April 11, 2011 Mr. William R. Campbell, Jr.

UNITED STATES
NUCLEAR REGULATORY COMMISSION
REGION II
245 PEACHTREE CENTER AVENUE NE SUITE 1200
ATLANTA, GEORGIA 30303-1257
April 11, 2011
Mr. William R. Campbell, Jr.
Chief Nuclear Officer and Executive Vice President
Tennessee Valley Authority
6A Lookout Place
1101 Market Street
Chattanooga, TN 37402-2801
SUBJECT:
WATTS BAR NUCLEAR PLANT UNITS 1 AND 2 MULTI-UNIT OPERATOR
TRAINING AND CERTIFICATION PROGRAM, REVISION 1
Dear Mr. Campbell, Jr.:
In a letter dated November 18, 2010, the Tennessee Valley Authority (TVA) provided changes
to its initial approach for ensuring that a sufficient number of licensed operators will be available
to operate Watts Bar Nuclear Plant (WBN), Units 1 and 2, prior to Unit 2 initial fuel load. The
changes to the proposed initial training and certification program submittal also addressed
comments that members of your staff received from Region II Operations Branch during a
meeting on November 4, 2010. The reviewed training plan from TVA dated November 18,
2010, is attached.
The purposes of the Region II Operator Licensing staff’s review of the proposed training plan
and the planned inspection activities are to:
•
Evaluate the differences between Unit 1 and Unit 2 and provide insight to the office of
Nuclear Reactor Regulation (NRR), headquarters Operator Licensing Branch, to identify if
currently licensed operators on Unit 1 who will be requesting Watts Bar Unit 2 (dual)
licenses have had sufficient operating experience at a comparable facility as required by 10
CFR 55.47 (a)(1), that is on Watts Bar Unit 1, and that this operating experience has
occurred within two years prior to Unit 2 initial fuel load.
•
Evaluate the content of the proposed “differences” training provided to operators who are
currently licensed on Unit 1, to identify if training includes comprehensive “differences”
written examinations, JPM operating tests, and simulator modifications, training that meets
the requirements of 10 CFR 55.47 (a)(3) in that each applicant “has learned the operating
procedures for and is qualified to operate competently and safely” Watts Bar Unit 2.
Additionally, the purpose of the evaluation is to ensure that incumbent operators, as well as
initial operator license applicants, have startup training using Unit 2 initial criticality
procedures on the plant reference simulator using a simulator model that approximates Unit
2 core design.
•
Evaluate the adequacy of the Unit 1 simulator for administering operating tests to initial
operator applicants, in accordance with 10CFR 55.46, during the same time frame that the
simulator will be used to train licensed operators on the Unit-2 modifications.
TVA
•
2
Evaluate the content of the proposed “differences” training including the proposed
evaluation methods that will be administered to initial operator license applicants who will
only be issued Unit 1 operating licenses prior to obtaining a dual unit license.
Based on Region II Operator Licensing’s review of the available Unit 2 modifications, the
proposed differences between Unit 1 and Unit 2 are not so significant that they would affect the
operator’s ability to operate each unit safely and competently. Approximately ten percent of the
required modifications are yet to be issued. The final determination of whether the operators
who are currently licensed on Unit 1 meet the written and operating test waiver requirements, in
accordance with 10CFR55.47 and NUREG 1021, Revision 9, Supplement 1, ES-204, Section
D.2, on Unit 2 is contingent upon Region II Operator Licensing inspections, and completion of
the proposed training plan “Multi-Unit Operator Training and Certification Program, Revision 1.”
Sincerely,
/ RA /
Malcolm T. Widmann, Chief
Operations Branch 1
Division of Reactor Safety
Docket No(s).: 50-390, 50-391
License No(s).: NPF-90, CPPR-92
Enclosure: As stated
cc w/encl: (See page 3)
TVA
•
2
Evaluate the content of the proposed “differences” training including the proposed
evaluation methods that will be administered to initial operator license applicants who will
only be issued Unit 1 operating licenses prior to obtaining a dual unit license.
Based on Region II Operator Licensing’s review of the available Unit 2 modifications, the
proposed differences between Unit 1 and Unit 2 are not so significant that they would affect the
operator’s ability to operate each unit safely and competently. Approximately ten percent of the
required modifications are yet to be issued. The final determination of whether the operators
who are currently licensed on Unit 1 meet the written and operating test waiver requirements, in
accordance with 10CFR55.47 and NUREG 1021, Revision 9, Supplement 1, ES-204, Section
D.2, on Unit 2 is contingent upon Region II Operator Licensing inspections, and completion of
the proposed training plan “Multi-Unit Operator Training and Certification Program, Revision 1.”
Sincerely,
/ RA /
Malcolm T. Widmann, Chief
Operations Branch 1
Division of Reactor Safety
Docket Nos.: 50-390, 50-391
License Nos.: NPF-90, CPPR-92
Enclosure: As stated
cc w/encl: (See page 3)
X PUBLICLY AVAILABLE
ADAMS: X Yes
G NON-PUBLICLY AVAILABLE
X SUNSI REVIEW COMPLETE
ACCESSION NUMBER: ML 111010586
OFFICE
SIGNATURE
RII:DRS
RA
RII:DRS
RA
RII:DRS
RA
NAME
R. Baldwin
M. Widmann
M. Franke
DATE
04/11/2011
E-MAIL COPY?
YES
NO
OFFICIAL RECORD COPY
APPROVAL LETTER.DOCX
04/11/2011
YES
NO
X NON-SENSITIVE
G SENSITIVE
04/11/2011
YES
DOCUMENT NAME:
NO
YES
NO
YES
NO
YES
NO
YES
G:\DRSII\OBII\SITES\WATTS BAR\NEW UNIT 2\TRAINING PLAN
NO
TVA
cc w/encl:
D. E. Grissette
Site Vice President
Watts Bar Nuclear Plant
Tennessee Valley Authority
Electronic Mail Distribution
G. A. Boerschig
Plant Manager
Watts Bar Nuclear Plant, MOB 2R-WBN
Tennessee Valley Authority
Electronic Mail Distribution
C. J. Riedl
Acting Manager, Licensing
Watts Bar Nuclear Plant, ADM 1L-WBN
Tennessee Valley Authority
P.O. Box 2000
Spring City, TN 37381
J. W. Shea
Manager, Corp. Nuclear Licensing - WBN
Tennessee Valley Authority
Electronic Mail Distribution
E. J. Vigluicci
Assistant General Counsel
Tennessee Valley Authority
Electronic Mail Distribution
W. D. Crouch
Licensing Manager, Unit 2
Watts Bar Nuclear Plant, EQB 1B-WBN
Tennessee Valley Authority
P.O. Box 2000
Spring City, TN 37381
County Mayor
P.O. Box 156
Decatur, TN 37322
County Executive
375 Church Street
Suite 215
Dayton, TN 37321
3
Tennessee Department of Enviornment &
Conservation
Division of Radiological Health
401 Church Street
Nashville, TN 37243
Senior Resident Inspector
U.S. Nuclear Regulatory Commission
Watts Bar Nuclear Plant
U.S. Nuclear Regulatory Commission
1260 Nuclear Plant Road
Spring City, TN 37381-2000
Ann Harris
341 Swing Loop
Rockwood, TN 37854
R. Krich
Vice President, Nuclear Licensing
1101 Market Street, LP 3R
Chattanooga, TN 37402-2801
William W. Thompson
Training Manager
Watts Bar Nuclear Plant
Tennessee Valley Authority
P.O. Box 2000
Spring City, TN 37381
Letter to William R. Campbell, Jr. from Malcolm T. Widmann dated April 11, 2011.
SUBJECT:
WATTS BAR NUCLEAR PLANT UNITS 1 AND 2 MULTI-UNIT OPERATOR
TRAINING AND CERTIFICATION PROGRAM, REVISION 1
Distribution w/encl:
V. McCree
L. Wert
C. Casto
J. Munday
H. Christensen
M. Franke
R. Croteau
W. Jones
G. Guthrie
C. Kontz
R. Baldwin
B. Caballero
P. Capehart
C. Evans
L. Douglas
J. McHale, NRR/DIRS/IOLB
P. Milano, NRR
OE Mail
RIDSNRRDIRS
PUBLIC
A
Tennessee Valley Authority
1101 Market Street, LP 3R
Chattanooga, Tennessee 37402-2801
R. M. Krich
Vice President
Nuclear Licensing
November 18, 2010
10 CFR 55.5
Mr. Luis A. Reyes, Regional Administrator
U.S. Nuclear Regulatory Commission, Region II
Marquis One Tower
245 Peachtree Center Avenue, NE, Suite 1200
Atlanta, Georgia 30303-1 257
Attn: Mr. Malcolm T. Widmann
Watts Bar Nuclear Plant, Units 1 and 2
Facility Operating License No. NPF-90
Facility Construction Permit No. CPPR-92
NRC Docket Nos. 50-390 and 50-391
Subject:
WATTS BAR NUCLEAR PLANT, UNITS I AND 2
MULTI -UNIT OPERATOR TRAINING AND CERTIFICATION
PROGRAM, REVISION I
Reference:
Letter from WA to NRC, “Watts Bar Nuclear Plants, Units 1 and 2 MultiUnit Operator Training and Certification Program and Request for
Review,” dated August 27, 2010
In the referenced letter, the Tennessee Valley Authority (WA) described its approa
ch
to ensuring that a sufficient number of licensed operators will be available to operate
Watts Bar Nuclear Plant (VVBN), Units 1 and 2 prior to Unit 2 initial fuel load. WA
described its plan to seek dual-unit operator licenses for prospective WBN, Unit 2
operators using a training program that was based on a rigorous analysis of the
differences between Unit 1 and Unit 2. In its submittal, WA included a summary of its
conclusions regarding the nearly identical design and operation of Unit 1 and Unit 2.
In addition, WA included a detailed report on WBN, Units I and 2 plant differences,
and its training plan.
WA has continued to review its dual-unit operator training plan and has developed
Revision 1 to the Watts Bar Unit Differences and Training Plan Report. A description
of the changes between Revision 1 and the version submitted in the Reference letter
is included as Enclosure 1 to this letter. Enclosure 2 to this letter is “Watts Bar Unit
Differences and Training Plan Report, Revision 1, November2010.”
printed on recycled paper
NOV 19 O
U.S. Nuclear Regulatory Commission
Page 2
November 18, 2010
TVA understands that the NRC currently intends to issue a letter with the results
of its
review of TVA’s analysis and plan. In addition, WA understands that the NRC
is
currently developing its inspection plans with regard to the dual-unit operator license
training program.
There are no new regulatory commitments in this letter. If you have any questions,
please contact me at (423) 751-3628.
Respectfully,
—fri
R. M. Krich
Enclosures:
1. Description of Changes from “Watts Bar Unit Differences and Training
Plan Report, August 2010” to “Watts Bar Unit Differences and Training
Plan Report, Revision 1, November 2010”
2. Watts Bar Unit Differences and Training Plan Report, Revision 1,
November 2010
cc: U.S. Nuclear Regulatory Commission Document Control Desk
-
Enclosure I
Description of Changes from “Watts Bar Unit Differences and Trainin
g
Plan Report, August 2010” to “Watts Bar Unit Differences and Trainin
g
Plan Report, Revision 1, November 2010”
Description of Changes from “Watts Bar Unit Differences and Training Plan Report,
August 2010” to “Watts Bar Unit Differences and Training Plan Report, Revision 1,
November 2010”
INTRODUCTION
WA has continued to review its dual-unit operator training plan and has developed Revision I
to the Watts Bar Unit Differences and Training Plan Report submitted in Reference 1. A
description of the changes to the “Watts Bar Unit Differences and Training Plan Report,
Revision 1, November 2010,” Enclosure 2, from the version submitted in the Referenced letter is
summarized below.
SUMMARYOF CHANGES
Section 1.3, 4th bullet was updated to provide additional details on the WBN 1 simulator
capabilities that would be used to support differences training.
Section 3.3.2 was updated to provide additional details on the WBN I simulator capabilities that
would be used to support differences training.
Section 3.3.2.c.5 was updated to provide additional details on the planned in-plant OJTITPE
topics.
Section 3.3.2.e was changed to include training on Unit 2 Initial Criticality Procedures and Unit 2
core design, and remove a second simulator demonstration of the Unit 2 steam generators.
Additionally, a third paragraph was added to clarify the licensee’s intentions on administering an
open book examination to test the licensed operators’ knowledge of the new Unit 2.
Section 3.3.2.f was changed to reflect a review of the Unit 2 Initial Criticality Procedures and
Unit 2 core design topics.
Section 3.3.2.g was updated to include additional details on the administering of the Biennial
LOR exams.
Section 3.4.2.a was updated to provide clarification and additional detail on the management of
the ILT Classes 11-06 and 11-10.
Section 3.5.2.a was changed to reflect a second simulator demonstration of the Unit 2 steam
generators to occur in cycle 11 vice cycle 10.
Section 3.5.2.b was changed to reflect training on Unit 2 Initial Criticality Procedures and Unit 2
core design to occur in cycle 10 vice cycle 11.
Table 2, Differences Training Scope, Duration and Schedule, was updated to reflect:
• Training on Unit 2 Initial Criticality Procedures and Unit 2 core design to occur in cycle
10 vice cycle 11.
•
An additional review of the Unit 2 Initial Criticality Procedures and Unit 2 core design
topics in cycle 11.
•
A second simulator demonstration of the Unit 2 steam generators to occur in cycle 11
vice cycle 10.
•
Additional details in notes section on the details for the simulator demonstration of the
Unit 2 steam generators.
•
Attachment 1, Detailed Plan Differences, was updated to provide additional details on
the differences between Unit I and Unit 2 Source Range and Intermediate Range
Monitors.
•
A clarification to the footnote on Page E2-71 regarding the implementation of the
Leading Edge Flow Meter for Unit 2.
Reference:
Letter from WA to NRC, “Watts Bar Nuclear Plants, Units I and 2 Multi-Unit
Operator Training and Certification Program and Request for Review,” dated
August 27, 2010
Enclosure 2
Watts Bar Unit Differences and Training Plan Report, Revision 1,
November 2010
I
-
m
ri
Table of Contents
TABLE0FC0NTENTs
2
L
3
EXECUTIVE SUMMARY
1.1
REGULATORY CoNsIDERATIoN
1.2
UNIT 2 DIFFERENCEs OVERVIEW
TABLE 1: UNIT 1 UNIT 2 DIFFERENCEs OVERVIEW
3
4
/
1.3
4
7
TRAINING PLAN SUMMARY
WATTS BAR ANALYSIS OF UNIT 1 AND UNIT 2 DIFFERENCES
2.1
2.2
NEARLY IDENTICAL SuMMARY
NEARLY IDENTICAL JUSTIFICATION
9
2.2.1
FACILITY DESIGN AND SYSTEMS RELEVANT TO CONTROL ROOM PERSONNEL
2.2.2
TECHNICAL SPECIFICATIONS
PROCEDURES (ABNORMAL AND EMERGENCY PROCEDuRES)
CONTROL ROOM DESIGN AND INSTRUMENT LOCATION
OPERATIONAL CHARACTERISTICS
11
12
12
14
14
15
22
ADMINISTRATIVE PROCEDURES RELATED TO CONDUCT OF OPERATIONS FOR A MULTI-UNIT SITE
24
ExPECTED METhOD OF ROTATING PERSONNEL BETWEEN UNITS AND RE-FAMILIARIZATION TRAINING TO BE
CONDUCTED BEFORE ASSUMING DUTY ON THE NEW UNIT
26
TRAINING AND OUALIFICATION PLAN
27
2.2.3
2.2.4
2.2.5
2.2.6
2.2.7
3.1
3.2
TRAINING ANALYSIS
TRAINING PLAN ASSUMPTIONS
3.3
DESCRIPTION OF TRAINING AND QUALIFICATION PLAN FOR PERSONNEL CURRENTLY LICENSED ON UNIT 1
3.3.1
3.3.2
3.3.3
3.4
LICENSED OPERATOR REQUALIFIcATI0N (LOR) TRAINING PLAN DESIGN
LORTRAINING PLAN SUMMARY
LOR ExAMINATION IMPACT OF PLANNED SIMULATOR MODIFICATIONS
27
28
29
29
29
33
DESCRIPTION OF TRAINING AND QUALIFICATION PLAN FOR PERSONNEL IN CURRENT AND FUTURE INITIAL
LICENSE CLASSES
3.4.1
3.4.2
3.4.3
INITIAL LICENSE TRAINING (ILT) PLAN DESIGN
ILT TRAINING PLAN SUMMARY
ILT ExAMINATION IMPACT OF PLANNED SIMULATOR MODIFICATIONS
3.5
MAINTAINING SIMULATOR ALIGNMENT WITH THE REFERENCE UNIT 1
SIMULATOR CONFIGURATION PLAN DESIGN
3.5.1
3.5.2
SIMULATOR CONFIGURATION PLAN SUMMARY
TABLE 2: DIFFERENCES TRAINING SCOPE, DURATION, AND SCHEDULE
ATTACHMENT 1
—
DETAILED PLANT DIFFERENCES
ATTACHMENT 2 -TECHNICAL SPECIFICATIONS DIFFERENCES
ATTACHMENT 3- NRC GUIDANCE
ATTACHMENT 4-ACRONYMS
ATTACHMENT 5 UNIT COMPARISON CONTROL ROOM PHOTOS
FIGURE 1 INTEGRATED TIMELINE
FIGURE 2 CONTROL ROOM LAYOUT
—
—
—
E2-2
33
33
34
35
35
35
35
37
40
70
72
74
76
92
93
1.
Executive Summary
This report meets the criteria spelled out in NUREG 1021, section ES 204 which defines
utility requests for dual unit licenses for the licensed operators of the facility. Part of that
request is to justify why the utility believes the two units are “nearly identical” and to
describe the training plan for operators to inform them of any existing unit differences.
In 2007 Tennessee Valley Authority (TVA) decided to recommence construction on
Watts Bar unit 2. During the lead up to this decision and continuing into construction
activities, TVA management put in place expectations that the design and construction
groups would maintain fidelity between Unit 1 and Unit 2. This expectation was
enforced through memorandum, procedures and processes, which required all parties to
ensure that Unit 2 would match Unit 1 to every extent possible.
This report provides justification as to why TVA considers the two units at Watts Bar
“nearly identical” and identifies a comprehensive training plan for currently licensed
operators and future licensed operators. It also provides assurance that the simulator
maintains fidelity with its plant-referenced unit. By showing that this guidance is
satisfied, TVA requests NRC review and approval of the following training plan. Based
on this approval, TVA plans to submit dual unit license applications and waivers of NRC
administered license examinations for Unit 2 where appropriate.
Regulatory Consideration
1.1
This plan provides the outline and approach to obtaining dual-unit operator licenses to
support the loading of fuel at the Watts Bar Unit 2 nuclear station.
This is a two-step process as outlined in NUREG 1021, ES-204 (see Section 4.0 for the
full text), which states, in part, that:
1. Facilities may request dual licensing for their operators.
2. Facilities may request a waiver of the examination requirement for the second
unit.
In either case the facility must justify that the units are “nearly identical” including:
•
facility design and systems
•
technical specifications
•
procedures (mainly abnormal and emergency procedures)
•
control room design and instrument location
•
operational characteristics
•
administrative procedures related to conduct of operations for a multi-unit site
•
expected method of rotating personnel between units and re-familiarization
training to be conducted before assuming duty on the new unit
E2-3
1.2
Unit 2 Differences Overview
The design of Unit 2 was conducted with the constraint of maintaining unit differences at
a minimum. Accordingly, every effort was made to minimize differences between the
units when installing new components on Unit 2, due to obsolescence of those
components on Unit 1. With Unit 2 design freeze recently established, a thorough
analysis of the unit differences has shown that the units remain nearly identical. Some of
the differences are listed here and are discussed in more detail in Section 2.0.
Table 1 provides an executive summary of the main differences between Units 1 and 2.
Table 1: Unit 1 / Unit 2 Differences Overview
Steam
Generators
Unit 1 has the 68AXP Replacement Steam Generator. Unit 2 has the D-3
Original Steam Generator.
(Photos not to scale)
,
r
I1
I 1[
SG
Main
Turbine
The Unit 2 turbine has been updated to improve efficiency and power
output and is more tolerant to condenser backpressure.
This turbine has no impulse chamber. A tap and pressure transmitter will
be added to each of the four inlet lines from the control valves. For the
purpose of input to rod control, steam dumps and turbine runback, the
control signal will be the median of four signals.
Moisture
Separator
Reheaters
The secondary side moisture separator/reheaters for Unit 2 are an
upgraded design to enhance secondary side efficiency.
E2-4
Reactor
Vessel
Level
Indication
System
(RVLTS)
and
Inadequate
Core
Cooling
Monitor
(ICCM)
Unit 1 uses the RVLIS ICCM-86 system:
Unit 2 will use the Common Qualified (Common
Monitoring System (PAMS).
E2-5
Q) Post Accident
Digital
Control
system
(DCS)
Unit 2 will have digital controls for several systems including Feedwater
level control, Boration/Dilution Flow, Hotwell Level, Steam Generator
Blowdown, Rod Control Inputs, Pressurizer Pressure, Pressurizer Level,
Charging Flow, Letdown Flow, Main Feed Water Pump Flow Control,
Volume Control Tank Level, Residual Heat Removal flow, Steam
Generator Power Operated Relief Valves (PORVs), and Steam Dumps.
The Unit 2 digital control system will have increased fault tolerance
compared to the existing Unit 1 analog controls.
Unit 1 will receive an upgrade from the current analog controls to digital
controls for Feedwater, Pressurizer level, Pressurizer pressure and
boration controls in a refueling outage scheduled for October 2012.
The simulator (Unit I reference) will be upgraded to digital controls in
January 2012. The Unit 1 plant-referenced simulator will be modified to
include the Unit 1 digital controls almost concurrently with the planned
Unit 2 fuel load and will lead the actual Unit 1 installation by
approximately 10 months. This will provide for a full scope simulation
environment for the Foxboro Intelligent Automation (I/A) digital controls
during the power ascension-testing phase of the Unit 2 project.
The digital control feature that enables the operator to enter control
system inputs via a computer terminal will be electronically blocked from
Unit 2. Manipulation of equipment will only be permitted from the
control panels.
Reactor
Fuel
Incore
Probes
Unit 1 will have a steady state fuel load.
Unit 2 will have a new core.
Unit 1 uses Westinghouse movable probes.
Unit 2 will use the Westinghouse In-Core Information Surveillance &
Engineering (WllJCISE) system (Incore fixed sensors).
E2-6
1.3
Training Plan Summary
•
Approximately 124 hours of training are planned for Unit 2 Fuel Load readiness
and the differences between the units. The Licensed Operator Requalification
(LOR) training will be conducted on common systems, unit differences, Unit 2
procedures and Technical Specifications. The training will consist of classroom
lectures, vendor supplied equipment/mockups, structured in-plant tours, training
on the Sequoyah simulator, completion ofjob familiarization guides and
completion of qualification cards (formal On-the-Job-Training and Task
Performance-Evaluation, OJT/TPE). This training will take place from
September 2010 through September 2011 prior to the September 19, 2011 license
application submittal for dual unit licenses for operators with a license to operate
Unit 1. Additional training will continue through Unit 2 hot functional testing,
fuel load, initial criticality and start up testing, but will not be credited towards the
request for dual unit licenses, since it occurs after the license application
submittal.
•
Watts Bar staff, with NRC approval of waiver of NRC administered license
exams, will conduct operator testing and certification on Unit 2.
•
The Sequoyah simulator will be used for part of the training and evaluation on
digital controls prior to Unit 2 fuel load.
•
TVA has evaluated the ability to provide simulation capabilities for plant
differences that will exist at the startup of Unit 2 using the Watts Bar simulator.
•
o
The simulator has the capability of using temporary computer models for
the original (D-3) steam generators which will be used for training the
operators prior to Unit 2 fuel load.
o
The simulator has the capability of using temporary computer models for
the initial core load which will be used for training the operators prior to
Unit 2 fuel load.
The Watts Bar simulator will be upgraded to DCS in January 2012. This will
precede the Unit 1 plant upgrade to DCS by 10 months. The timing of the
simulator upgrade allows for a continuation of training on digital controls during
Unit 2 start-up testing, power-ascension and prior to implementation of DCS on
Unit 1 plant. This will provide additional reinforcement and proficiency on the
DCS system.
Note: Initial license classes are numbered with the year and month the class
takes the NRC exam, i.e., class 11-06 takes the NRC exam in June of2Oll.
•
Initial License Training (ILT) Classes 11-06 and 11-10 are scheduled for their
NRC Examinations in June 2011 and October 2011, respectively which are prior
to Unit 2 fuel load in December 2011. Both classes will train and examine on the
Unit 1 referenced simulator and their license applications will request a Unit 1
License. After receipt of their NRC licenses, these individuals will complete the
LOR Unit Differences Training and examination described in section 3.0 of this
E2-7
report. Request for dual unit licenses will come in a second license application
submittal, along with request for a waiver to NRC administered exams.
•
ILT Class 12-11 will take their NRC Examination in November 2012, this is after
the Unit I reference simulator is upgraded to digital controls in January 2012 and
after Unit 1 Main Control Room (MCR) is upgraded in October 2012. These
students will be trained on Unit 1 and Unit 2 differences, during the course of
their ILT class. This class will use the DCS upgraded simulator. This class will
submit License Applications for both a Unit 1 and Unit 2 License.
E2-8
2.
Watts Bar Analysis of Unit 1 and Unit 2 Differences
TVA suspended construction of Watts Bar Nuclear (WBN) Unit 2 in 1985, placed the
unit in construction layup status, and formally deferred WBN Unit 2 in 2000. In 2007
TVA decided to recommence construction on Watts Bar Unit 2. During the lead up to
this decision and continuing into construction activities, TVA management put in place
expectations that the design and construction groups would maintain fidelity between
Unit 1 and Unit 2. This expectation was enforced through memorandum, procedures and
processes, which required all parties to ensure that Unit 2 would match Unit 1 to every
extent possible. This is demonstrated in numerous documents where the intent to
maintain fidelity between units is spelled out in communications internal to TVA and
also in communications to the NRC.
In a letter dated April 3, 2007 (L44 070403 001) TVA asked for feedback from the NRC
on certain assumptions TVA was making in the time leading up to a final decision to
recommence construction on Unit 2. TVA describes one assumption as being able to
resume construction and
.use the existing Part 50 construction permit and the largely
completed and well documented operating license review framework. This is the first
key regulatory assumption. This first key regulatory assumption is grounded on the fact
that WBN 2 is of the same vintage and would be virtually identical to WBN Unit 1.
From a regulatory perspective, this means that the WBN Unit 2 licensing and design
basis would be essentially the same as what presently exists for WBN Unit 1.”
“. .
In a letter from the NRC to TVA dated July 25, 2007 (Staff Reguirements-SECY-070096-Possible Reactivation of Construction and Licensing Activities for the Watts Bar
Nuclear Plant Unit 2), the NRC stated:
“The Commission supports a licensing review approach that employs the current
licensing basis for Unit las the reference basis for the review and licensing of
Unit 2.”
In a letter from TVA to the NRC dated August 3, 2007, titled “Watts Bar Nuclear Plant
(WBN) Unit 2 Reactivation of Construction Activities” the following excerpts
demonstrate TVA’ s intent to keep the two units similar:
—
—
“As background, on October 4, 1976, TVA submitted a dual unit WBN Operating
License (OL) for both WBN Unit 1 and Unit 2. WBN Unit 1 received a full power
OL on February 7, 1996. WBN Unit 2 which was placed on deferred status would
be operationally the same as Unit 1 at startup. TVA believes that, from regulatory,
safety and plant operational perspectives, significant benefit is gained from
aligning the licensing and design bases of WBN Units 1 and 2 to the fullest extent
practicable. The commission recognized these benefits in Reference 2.”
(Reference 2 in this letter is referring to the NRC letter discussed above dated July
25, 2007)
E2-9
“In furtherance of this objective, TVA will complete WBN Unit 2 in compliance
with applicable regulations promulgated prior to and after the issuance of the
WBN Unit 1 OL. In addition, the WBN Unit 2 licensing and design bases will
incorporate modifications made to WBN Unit 1, and those modifications
currently captured in the WBN Unit 1 five-year plan. This alignment of the WBN
Unit 1 and 2 licensing and design bases will ensure that there is operational
fidelity between units and at the same time demonstrate and ensure that WBN
Unit 2 complies with applicable NRC regulatory requirements.”
The Watts Bar Detailed Scoping, Estimating, and Planning (DSEP) study dated 06/18/07,
provided guidance for the continuation of construction of Watts Bar Unit 2 as follows:
“The Engineering Baseline and Modification organizations will prepare design
criteria, design calculations, procurement and installation specifications, develop
drawings and specifications, and issue procurement documents that provide
detailed design for construction as required for completing WBN2. While
Engineering work will be performed to the A/E’s procedures, calculations and
DCNs will conform to TVA’s Engineering Change Control and Plant
Modification procedures with an emphasis on ensuring fidelity with Unit 1.”
(bolded emphasis was added)
The Watts Bar Unit 1 and 2 Memorandum of Understanding, which defines the division
of responsibilities between unit 1 and unit 2, under the Design Engineering Interface,
states:
“One of the goals of the Unit 2 completion is to maintain as much consistency in
configuration and processes with unit 1 as possible. Unit 2 will develop
requirements and a means for tracking differences that exist or are created
between the two units. Part of the Unit 2 scoping process will be to evaluate the
as-constructed Unit 1 configuration against the Unit 2 as-designed configuration
and Unit 2 walkdown results to determine what physical changes are required to
Unit 2 to maintain configuration consistency. Differences between the two units
will be reviewed and agreed upon by the two units.”
As an example of the management processes in place during Unit 2 construction, the
construction contractor had an Engineering procedure (25402-3DP-GO4G-00081) which
required any differences between the units to be documented and reviewed by
Operations, Maintenance and Engineering organizations. Part of this review process also
included analysis of the differences for inclusion into the operator differences training.
Unit 1 modifications were reviewed and a Unit 2 scope work list was developed from this
review. For each Corrective Action Program (CAP) and Special Program (SP) a plan for
Unit 2 was developed to implement the changes associated with each program based
upon a review of Problem Evaluation Reports (PER5), Nuclear Central Office Tracking
items (NCOs), Category Drawings (CATDs), and Unit 1 corrective actions. Engineering
E2-1O
Design Control Requests (EDCRs) were issued for the CAPs and SPs based on this
review.
Due to equipment obsolescence some new designs for Unit 2 were needed (Foxboro
DCS, Unit 2 Annunciator, Rosemount Transmitters, etc.).
Unit 2 designs were evaluated for any unit differences with Unit 1. These differences
were reviewed and approved by TVA operations, maintenance, and engineering groups.
As documented in the examples given above, during design and construction activities,
every effort was made to minimize differences between the units. When installing new
components on Unit 2 due to obsolescence of those components on Unit 1 similar
controller type and sizes were used, wherever possible, to keep the control and indication
locations the same on the Unit 2 Main Control Panels.
2.1
Nearly Identical Summary
This section will provide a brief overview of how the two units at Watts Bar have been
determined to be “nearly identical”, as the terminology in NUREG 1021 states. More
detail follows in section 2.2.
•
The units consist of identical nuclear steam supply system (NSSS) vendor designs
and secondary plant designs. Unit 2 will include the original D-3 steam
generators and Unit 1 has installed 68AXP replacement steam generators.
•
Initially, the units will have different core operating characteristics with Unit 1
being in a normal first/second/third burn assembly fuel cycle. Unit 2 will consist
of all first burn assemblies. The actual operator impact is not significant.
•
The technical specifications and structure of the operating procedures developed
for Unit 2 will be nearly identical to those already in use for Unit 1.
•
Unit 1 uses Westinghouse movable incore probes. Unit 2 will have WINCISE
fixed sensors, which also house the Core Exit Thermocouples.
•
Reactor vessel level and cooling monitoring systems on Unit 1 uses the RVLIS
(ICCM-86) system and Unit 2 will have the Common Q system. The Common
system has slightly different mimics but the same information is displayed.
•
Q
There will be analog vs. digital controls with Unit 2 leading Unit 1 in the upgrade
to digital control systems. At fuel load in December 2011, Unit 2 will utilize a
Foxboro Intelligent Automation (I/A) model digital control system (DCS).
Approximately 10 months later, Unit 1 will have the same system installed but
with a limited scope of controllers compared to Unit 2. Digital modification of
one unit followed by a second unit at a dual-unit station is a typical industry
practice and Watts Bar will follow this traditional approach.
E2-11
2.2
Nearly Identical Justification
This section includes the analysis and the nearly identical justification performed by
Watts Bar to meet NUREG 1021, ES-204 guidance as listed below and will follow the
format of the bulleted items listed in the NUREG.
2.2.1 Facility Design and Systems relevant to Control Room Personnel
2.2.1 .a The WBN Unit 1 steam generators were replaced. The Unit 2 generators
remain the original D-3 model, which has some operational differences
setpoints on Unit 2 the same as Unit 1.
2.2.1 .b The Unit 2 turbine has been updated to improve efficiency and power
output and is more tolerant to condenser backpressure. This turbine has
no impulse chamber. Therefore a tap and pressure transmitter will be
added to each of the four inlet lines from the control valves. For the
purpose of input to rod control, steam dumps and turbine runback, the
control signal will be the median of four signals. This algorithm is
performed in Foxboro I/A. The Permissive interlocks and Anticipated
Transient Without SCRAM (ATWS) Mitigating System Actuation
Circuitry (AMSAC) will still be generated from a single transmitter.
Analog Electro-Hydraulic (AEH) control will use Generator Megawatts
rather than impulse signal when in Impulse Pressure Control (IMP IN).
2.2.1 .c
The secondary side moisture separator/reheaters for Unit 2 are an
upgraded design to enhance secondary side efficiency.
2.2.1 .d The Inadequate Core Cooling Monitoring System (ICCM) 86 for Unit 1
will be replaced with the Common Q platform for Unit 2. Parameters
present in the ICCM 86 will be in the Common Q PAMS including Core
Exit Thermocouples, RVLIS, and Core Saturation Monitor.
2.2.1 .e There will be analog vs. digital controls with Unit 2 leading Unit 1 in the
upgrade to digital control systems. At fuel load in December 2011, Unit
2 will utilize a Foxboro Intelligent Automation (I/A) model digital
control system (DCS). The primary impact of the DCS change will be
reduced susceptibility to transients caused by an instrument failure. For
instance;
2.2.1.e.l
A loss of a single Vital Inverter will no longer cause a unit
trip. This is due to the fault tolerance in the DCS feedwater
system and the pressurizer control system.
E2-12
2.2.1 .e.2
The Main Feedwater (MFW) Controls digital upgrade
modification has been designed to incorporate all functions
of the existing system, in addition to providing enhanced
monitoring and control methods and diagnostic capabilities.
Operator response to abnormal Steam Generator (SG)
Level, MFW Flow or MFW Pump Speed remains the same,
except that with the new DCS and new field input signals,
additional redundancy is provided and potentially faulty
instrumentation is automatically bypassed. The new DCS
provides monitoring of all of the Feedwater Control System
parameters on the redundant video display monitors
installed on the operator’s desk. In addition, the DCS
provides a redundant link to the existing plant Integrated
Computer System (ICS) to provide Feedwater information
to the operator.
2.2.1 .e.3
Pressurizer control will no longer require manual operator
action on loss of a transmitter. This is due to transmitter
redundancy logic.
2.2.1 .e.4
Boric Acid Control will be incorporated into I/A. The
primary operational difference, other than the controllers
are changed to I/A, is that the Unit 2 system displays will
have digital displays and can be programmed for a desired
ppm boron concentration (vs. only gpm on Unit 1)
2.2.1 .f The incore probes on Unit 2 will be WINCISE fixed probes as opposed
to the Unit 1 Westinghouse movable. The WINCISE probes will also
house the Core Exit Thermocouples. This will impact the indicated
temperature slightly but will not impact post accident temperatures or
Emergency Operating Instructions (EOI) setpoints.
2.2.1 .g Unit 2 will eliminate the Post Accident Sampling System (PASS) and
physically remove the associated equipment. Unit 1 has abandoned the
PASS system in place.
2.2.1 .h There will be only one Hydrogen Analyzer for Unit 2 and it will be nonsafety related.
2.2.1 .i
The hydrogen recombiners on Unit 1 have been removed from Technical
Specifications. The handswitches for Unit 1 are still on the control room
panel 1 -M- 10. The hydrogen recombiners on Unit 2 will be abandoned
in place and the handswitches in the control room have been removed
from panel 2-M- 10.
E2-13
2.2.2 Technical Specifications
Watts Bar Unit 1 and Unit 2 have separate Technical Specification(s) (IS) and Technical
Requirements Manual (TRM). TVA used the WBN Unit 1 TS and TRM to develop the
proposed WBN Unit 2 TS and TRM. The numbers, setpoints, and parameters provided
have been validated through the design phase of the construction completion project. All
Nuclear Steam Supply System (NSSS) setpoints are identical; therefore TS related
setpoints will be identical between the units. Final verification will be provided as part of
the “as-built” phase of construction completion of WBN Unit 2.
Watts Bar has thoroughly reviewed the technical specifications differences and
determined that they are nearly identical. This is based on minimal differences between
the Unit 1 and Unit 2 technical specifications. Attachment 2 provides a detailed
discussion for each of the identified technical specification differences.
2.2.3 Procedures (Abnormal and Emergency Procedures)
Watts Bar has thoroughly reviewed the Unit 1 abnormal and emergency procedures
against the intended structure and content of the Unit 2 procedures and has determined
that they are nearly identical.
The Unit 2 Emergency Operating Instructions (EOIs) will be developed to the same
revision level and the exact format as the suite of Unit 1 EOIs currently in use today. The
EOIs are symptom-based procedures and there is no change in logic for implementation
as a result of any differences in design and control. Not all of the setpoint calculations
pertaining to EOI actions have been completed at this time. As remaining setpoint data is
received, any differences will be rolled into the scheduled operator training. Based on
calculations already completed, it is not anticipated these setpoint differences will be
significant. Unit specific EOIs will be developed to prevent human errors related to
combining Unit procedure steps.
The Unit 2 Abnormal Operating Instructions (AOI5) will be developed to the same
revision level and two-column format as the suite of AOIs utilized to operate Unit 1. A
numbering system will be in place to allow for Unit specific AOIs, where needed, to
prevent human errors related to combining Unit procedure steps. The majority of the
AOIs have been drafted and the primary differences were related to DCS. These
differences are minor, and result in fewer operator actions associated with instrument
failures, making the AOIs less complicated to implement. Entry conditions and
symptoms described in the AOIs are the same for Unit 2 as for Unit 1.
E2-14
2.2.4 Control Room Design and Instrument Location
Watts Bar has thoroughly reviewed the control room design and instrument locations and
determined that they are nearly identical.
The Unit 2 Main Control Board layout is a rotated image of the Unit I Main Control
Boards. On panels M-l through M-6, the left-right relationship for controls and
indications is nearly identical.
The control room design and instrument locations differences are mainly attributed to
DCS components that are functionally the same as their corresponding Unit I
components with minimal changes in their arrangement and appearance.
The new controllers use digital pushbuttons for Auto/Manual selection and raise/lower
functions that send a signal through the DCS. The previous analog controllers used a dial
for setpoint adjustment, and a toggle lever to control the raise/lower and manual
functions. These signals were sent through the control loops directly.
The Manual / Auto hand control stations controller boxes do not have the electronics or
active components to perform any automatic control functions. They provide process and
setpoint information indication, and provide an interface point for the operator to take
manual control of the device, and/or to adjust the setpoint or the output to the device.
The actual controls exist in the DCS processors. The size, shape, color, and legend for
the meters and pushbuttons on the controller faceplates are consistent with the existing
controllers on Unit 1. The orientation of the meter scale is in the horizontal position, and
the movement of the indicator needle along the scale is consistent with other existing
meters. The increase (>>) and decrease (<<) pushbuttons are logically positioned on the
face plate with the increase push button on the right side and the decrease push button on
the left side, which is consistent with direction of movement expectations. The push
buttons are equipped with back light LEDs, which illuminate to indicate position status.
Additionally, based on the improved functionality and automation of the DCS, obsolete
switches were not needed and were removed. The following provides an overview of the
identified control room design and instrument location differences. Attachment 1
provides additional details.
2.2.4.a Main Control Board Panel 2-M-1 “Auxiliary Power”
2.2.4.a.l
Main Control Room panel 2-M-1 has an ICS display
monitor 2-MON-47-120. This monitor duplicates the
functionality of obsolete recorders 2-TR-47- 1 and 2-TR-472. On Unit I these recorders (1 -TR-47- 1 and 1 -TR-47-2)
were abandoned and the inputs to these recorders were
provided to the plant computer system (ICS).
E2-15
2.2.4.b Main Control Board Panel 2-M-2 “Turbine Generator Controls”
2.2.4.b.1
2.2.4.c
Hotwell level controllers 2-LIC-2-3 and 2-LIC-2-9 and
Raw Cooling Water Supply controllers 2-TIC-24-48, and 2TIC-24-69 will be Foxboro I/A type controllers, while on
Unit 1 these controllers are GEMAC type controllers.
Main Control Board Panel 2-M-3 “Feedwater and Condensate”
2.2.4.c. 1
Hand switch 2-HS-3-45 is a 4-position switch to warm the
main feedwater lines through forward and back flush
operations. The Unit 1 steam generators were changed,
which eliminated the need for back flush operations: 1 -HS
3-45 is a two-position switch, without the back flush
operation mode. Status light box 2-XX-3-235 retains
additional lights related to back flushing operations on the
steam generators.
2.2.4.c.2
Nuclear Instrumentation System (NIS) bias controllers 2LIC-3-231, 2-LIC-3-232, 2-LIC-3-233, and 2-LIC-3-234
are eliminated from panel 2-M-3, while they remain on
Unit 1. On Unit 1, a single channel of NIS power is used to
determine the setpoint for each loop. On Unit 2, the
Foxboro I/A control system will select the second highest
of the four channels of NIS power.
2.2.4.c.3
The following controllers are replaced with Foxboro I/A
type controllers on 2-M-3:
• 2-LIC-3-35A, -48A, 90A, and 103A (Steam Generator 1
4 MFW Bypass Controllers)
• 2-FIC-3-35, -48, -90, and -103 (Steam Generator 1 —4
Feedwater Inlet Flow Controllers)
• 2-FIC-3 -70, -84, and -208 (Feedwater Pump Flow
Controllers)
• 2-PC-46-20, 2-SIC-46-20A and -20B (MFPT Speed
Controllers)
2.2.4.d Main Control Board Panel 2-M-4, “Reactor Controls”
E2-16
—
2.2.4.d.1
Steam Generator Blow Down hand-switches 2-HS-1-7/181,
14/182, 25/183 and 32/184 and the indicating lights for
these switches are oriented in different configuration than
on Unit 1. On Unit 1, these hand-switches and their
associated indicating lights are arranged in a row. On Unit
2, these hand-switches and their associated indicating lights
are arranged with two switches in one row and with the
other two switches mounted directly above. This relocation
was necessary due to the increased mounting area needed
to install four Foxboro I/A controllers, located adjacent to
the Steam Generator Blow Down hand-switches.
2.2.4.d.2
The following controllers are replaced with Foxboro I/A
type controllers on 2-M-4:
• 2-PIC-1-6A, -13A, -24A, and -31A (Steam Generator 1-4
PORV Controllers)
• 2-PIC-1-33 (Steam Dump Pressure Controller)
• 2-HIC-15-43 (Steam Generator Blowdown Controller)
• 2-PIC-68-340A, -340B, and -340D (Pressurizer Pressure
Spray and Master Controllers)
• 2-LIC-68-3 39 (Charging Flow/Pressure Level Controller)
2.2.4.d.3
Transfer switches XS-1-3D, -IOD, -21D, and 28D (Steam
Generator 1-4 Main Steam Header Flow), and XS-3-35D,
48D, 90D, and -103D (Steam Generator 1-4 Feedwater
Inlet Flow) will not be installed on Unit 2 because these
switch functions are automatically selected by the Foxboro
I/A control system.
-
2.2.4.d.4
Core Exit Temperature recorder 2-TR-94-1O1, switch 2XS-68-1O1, and RVLIS indicator 2-XI-68-100 will not be
installed on 2-M-4. The new COMMON Q display 2MON-68-100 will perform these functions for Unit 2.
2.2.4.d.5
Auxiliary Feedwater (AFW) motor driven pump discharge
pressure controllers 2-PDIC-3 -1 22A and 2-PDIC-3 -1 32A
(Auxiliary Feedwater Pumps A-A and B-B Discharge
Pressure Controllers) located on panel 2-M-4 have been
replaced with Foxboro SPEC 200 controllers. These
controllers perform the same function as the components
used in Unit 1. On Unit 1 these components are GEMAC
controllers. Unit 1 does use SPEC 200 on the level control
valves so the operation is familiar to the operators.
E2-17
2.2.4.d.6
2.2.4.e
Reactor Vessel Head Vent Throttle Valve controllers 2HIC-68-396 and 2-HIC-68-397 have been replaced with
Foxboro SPEC 200 controllers. These controllers perform
the same function as the Westinghouse controllers used in
Unit 1.
Main Control Board Panel 2-M-5, ‘Reactor Coolant System”
2.2.4.e. 1
The following controllers are replaced with Foxboro I/A
type controllers on 2-M-5:
• 2-HIC-62-56A (Excess Letdown Heat Exchanger Flow
Controller)
• 2-HIC-62-89A (Charging Header Reactor Coolant Pump
Seals Controller)
• 2-HIC-62-93A. (Charging Header Flow Controller)
2.2.4.e.2
Pressurizer level control (LIC-68-339): On Unit 1, there is
a selector switch (XS-68-339E) to select the level
transmitter used as input. On Unit 2, a similar switch will
be provided. The Unit 2 switch will have an additional
position, “auto”, which will allow the software to use a
median select. On Unit 1, there is a second selector switch
(XS-68-339B) that selects the transmitter signal going to
the recorder; this switch is eliminated on Unit 2 and the
signal used for control will go to the recorder.
2.2.4.e.3
Pressurizer pressure control (PIC-68-340): On Unit 1, there
is a selector switch (XS-68-340D) to select the pressure
transmitter used as input. On Unit 2, a similar switch will
be provided. The Unit 2 switch will have an additional
position, “auto”, which will allow the software to use a
median select. On Unit 1, there is a second selector switch
(XS-68-340B) that selects the transmitter signal going to
the recorder. This switch is eliminated on Unit 2, and the
signal used for control will go to the recorder.
2.2.4.e.4
Main Control Board Panel 2-M-6 “Engineered Safeguards”
(2-M-6 Right Half) (2-M-6 Left Half)
2.2.4.e.5
The Cold Leg Accumulators group of indicators (LI-63129, -119, -109, -99, -89, -81, -82, and -60 and P1-63-128,
126, -108, -106, -88, 86, -61, and -61) are located below the
new Common Q driver RVLIS ICCM monitor (2-MON68-110) on panel 2-M-6. On Unit, 1 these indicators are
located above RVLIS display (1-XI-68-1 10) on 1-M-6.
This was done to fit the new 15-inch Common Q display.
-
—
E2-18
2.2.4.e.6
Incore flux temperature recorder TR-94-102 is not installed
on panel 2-M-6. Common Q will pick up the data points.
The RVLIS display XI-68-1 10 and its keypad XS-68-1 11
on panel 1 -M-6 are not needed for panel 2-M-6, since their
functionality will be handled through Common Q monitor
2-MON-68-l 10. 2-MON-68-1 10 on panel 2-M-6 replaces
the functions supported by XI-68-l 10, XS-68-1 11, and TR
94-102 on l-M-6.
2.2.4.e.7
Boric Acid blending system (Foxboro I/A): Functionally
similar batch counters with digital displays will replace the
batch counters. Only two displays will be included, as it
was determined that a third counter at the bottom is not
used. The primary water flow controller’s setpoint will
display in gpm. The boric acid flow controller will have an
indicator that will indicate if the displayed setpoint is in
gpm or ppm. Ppm will be used for the automatic makeup
mode; gpm will be used for the other modes.
2.2.4.e.8
The following controllers are replaced with Foxboro I/A
type controllers on 2-M-6:
• 2-FC-62-139 and -142 (Boric Acid and Primary Water
Batch Counters)
• 2-FQ-62-139 and -142 (Boric Acid and Primary Water
Blender Controllers)
• 2-HIC-62-78A (Letdown Heat Exchanger Outlet
Temperature Controller)
• 2-HIC-62-81A (Letdown Pressure Controller)
• 2-HIC-62-83A (Residual Heat Removal Letdown Flow
Controller)
• 2-HIC-62-237 (Boric Acid Tank B Recirculation
Controller)
• 2-HIC-63-65A (Cold Leg Accumulator Nitrogen Vent
Controller)
• 2-HIC-74- 1 6A and -28A(Residual Heat Removal A/B Flow
Controllers)
• 2-HIC-74-32A (Residual Heat Removal A/B and Bypass
Flow Controller)
• 2-LIC-62-130A (Volume Control Tank Level Controller)
E2-19
2.2.4.f Main Control Board Panel 2-M-1O Temperature Monitoring
2.2.4.f.1
One of the Hydrogen Analyzers is being eliminated.
2.2.4.g Main Control Board Panel 2-M-1l Spare (Generator Core Condition
Monitor Unit I)
—
2.2.4.g. 1
The Hydrogen Purity Meter will be eliminated and placed
on ICS.
2.2.4.h Main Control Board Panel O-M-12 (Common Panel)
2.2.4.h. I
The following Radiation Monitors replaced with Digital
Units
• 2- RM-90-002 Personal Access Area Monitor (Personnel
Airlock)
• 2- RM-90-059 Upper Cntmt Area Monitor (Hatch)
• 2- RM-90-060 Upper Cntmt Area Monitor (Airlock)
• 2- RM-90-06 1 Incore Instrumentation Room
• 2- RM-90-106 Lower Cntmt Air
• 2- RM-90-1 12 Upper Cntmt Air
• 2- RM-90- 119 Condenser Vacuum Exhaust
• 2- RM-90-120 Steam Generator Building Effluent
• 2- RM-90-121 Steam Generator Building Effluent
2.2.4.i
Main Control Board Panel 2-M-13 Excore Neutron Instrumentation
2.2.4.i. 1
The Source and Intermediate Range Detectors will be
replaced with upgraded instruments that contain digital
indications in place of the Unit 1 analog meters.
E2-20
2.2.4.j
Main Control Board Panel 2-M-18 Westinghouse Incore Instrumentation
2.2.4.j.1
The movable Incore Probes have been replaced with
WINCISE and removed from 2-M-18.
2.2.4.k Main Control Board Panel 2-M-30 Post Accident and SG (Radiation)
Monitoring
2.2.4.k. 1
The following Radiation Monitors replaced with Digital
Units
• 2-RM-90-255 Condenser Vacuum Exhaust Low Range
• 2-RM-90-256 Condenser Vacuum Exhaust High Range
• 2-RM-90-27 1 Upper Cntmt High Range
• 2-RM-90-272 Upper Cntmt High Range
• 2-RM-90-273 Lower Cntmt High Range
• 2-RM-90-274 Lower Cntmt High Range
• 2-RM-90-42 I Main Steam Line Post Accident Monitor
• 2-RM-90-422 Main Steam Line Post Accident Monitor
• 2-RM-90-423 Main Steam Line Post Accident Monitor
• 2-RM-90-424 Main Steam Line Post Accident Monitor
2.2.4.1
Other Foxboro I/A Control System Changes (NSSS/BOP)
2.2.4.1.1
Operator workstations with flat panel displays, keyboards,
and mice will be provided in the MCR. The operator can
view real-time data and trends from these workstations.
2.2.4.1.2
The new system will provide alarm outputs to the
annunciator system identical to alarms in Unit 1. The new
system will provide two new alarms to the annunciator:
•
“DCS System Trouble” which alerts the operator that a
hardware failure has occurred and does not immediately
affect operability (there is a redundant system in place and
functional).
• “DC S Controller in Manual” which indicates that a failure
has occurred and requires that a 1oop be forced to Manual.
E2-21
2.2.4.m Auxiliary Control Room Panels 2-L-llA/B and L-10
2.2.4.m. 1
Corresponding controllers on the ACR panels will be
changed out to include the same type of Foxboro I/A &
Spec 200 controllers that are used on the Main Control
Room.
2.2.4.m.2
Switches on Unit 2 L-11A/B panels are located in different
locations than the Unit 1 Counterparts.
2.2.5 Operational Characteristics
2.2.5.a Unit 2 Reactor Core
Unit 2 will start up with a “clean” core and without Tritium Producing Burnable
Absorbers (TPBAR5). Initially, the units will have different core operating
characteristics: Unit 1 in a normal first/second/third bum assembly fuel cycle, Unit 2
with all first burn assemblies.
2.2.5.b Unit 2 Turbine Update
The Unit 2 turbine has been updated to improve efficiency and power output and is more
tolerant to condenser backpressure. This turbine has no impulse chamber. A tap and
pressure transmitter will be added to each of the four inlet lines from the control valves.
For the purpose of input to rod control, steam dumps and turbine runback, the control
signal will be the median of four signals. This algorithm is performed in Foxboro I/A.
The Permissive interlocks and AMSAC will still be generated from a single transmitter.
AEH will use Generator MW, rather than impulse signal, when in IMP fN.
2.2.5.c Unit 2 Steam Generator Response and Preheat Operations
Unit 2 will include the original D-3 steam generators and Unit 1 has installed 68AXP
replacement steam generators.
Unit 1 Steam Generators have a larger heat transfer area (20,000 ft
2 more) and a heat
transfer performance characteristic of 28.8 MW/F. The Unit 2 Steam generator has a
characteristic of 22.81 MW/F. The Unit 1 Heat transfer coefficient is slightly less than
that of Unit 2, however, the higher tube volume and more surface area results in a higher
Steam pressure and temperature at the same load.
The differences in steam generator design result in slightly different response
characteristics. The Unit 1 Steam Generators have a higher recirculation ratio, resulting
E2-22
in greater indicated level changes in response to transient/upset conditions. This has been
tempered to some extent by increasing the span of the level instrumentation. The Unit 2
Steam Generator indicated level response is slightly slower. This slight difference in
steam generator operations and response is similar to that experienced at other two unit
sites after upgrading their steam generators. These upgrades are typically done at
different times on opposite units, resulting in the two units having different steam
generators for some period of time.
The Unit 1 Steam Generators use a forward flush to warm the Main FW lines to the
steam generators, but no longer require a back flush. The Unit 2 Steam Generators
require a back flush for warming the Main FW lines to the steam generators. This is
accomplished by using an additional position added to the Unit 2 switch that controls the
forward flush.
2.2.5.d Unit 2 Digital Control System Upgrade
There will be analog vs. digital controls with Unit 2 leading Unit 1 in the upgrade to
digital control systems. At fuel load in December 2011, Unit 2 will utilize a Foxboro
Intelligent Automation (I/A) model digital control system (DCS). Approximately 10
months later, Unit 1 will have the same DCS system installed for Feedwater, Pressurizer
level, Pressurizer pressure and Boration controls.
Digital modification of one unit followed by a second unit at a dual-unit station is a
typical industry practice and Watts Bar will follow this traditional approach.
Operator workstations with flat panel displays, keyboards, and mice will be provided in
the MCR. The operator workstations will be configured such that the operators will be
able to view programmed displays. The operator workstations provide the capability of
displaying customized, dynamic color graphics of the processes. Additionally, the
operators will be able to monitor trend data, event logs and alarm priority levels. The
operator workstations will be configured (via password protection) such that no control
function will be allowed from the workstation.
The digital controllers in the DCS are designed to mimic the Unit 1 analog controllers.
The initial controller settings will be the same as those on Unit 1 and will use the same
algorithm, except for the steam generators. Steam Generators will use the Sequoyah
(SQN) algorithm. Testing performed at SQN indicates there is insignificant response
change due to the algorithm. Initial set up of the controllers on Unit 2 will use the
setpoint data (i.e. proportional and differential settings) established for the Unit 1
controllers. Tuning adjustments will then be made during Unit 2 start-up testing to
achieve the desired system response.
On Unit 1, a loss of power supply or failure of a controller will cause a loop to fail. Unit 2
will have redundant power supplies supplied from different sources, and redundant
control processors executing the control algorithms. On critical loops redundant
transmitters and redundant outputs to control valves are provided. Failures of
E2-23
transmitters / input signals on Unit 2 will result in smaller perturbations since the system
will automatically select a valid signal, if available, or place the controller into Manual.
The new system will provide alarm outputs to the armunciator system identical to alarms
in Unit 1. The new system also provides two new alarms to the annunciator, ‘DCS
System Trouble” which alerts the operator that a hardware failure has occurred which
does not immediately affect operability, i.e., there is a redundant system in place and
functional, and “DCS Controller in Manual” which indicates that a failure has occurred
which requires that a loop be forced to manual.
2.2.5.e
Plant Process Computer
The Plant Process Computer interface for the operator will be the same. Due to I/A,
much more information will be available on Unit 2.
2.2.5.f Unit 2 Moisture Separator Reheaters
The Unit 2 Moisture Separator Reheaters are higher capacity reheaters. Along with the
Main Turbine difference, the steam side of Unit 2 will operate at a slightly lower steam
pressure (about 45 psi lower). This will cause slightly different flows throughout the
system (extraction steam, heater drain flows) that will require different alarm setpoints.
All manipulations of system are proceduralized. Controls in MCR are the same for both
units.
Unit 2 Thermal Power will be limited to 3411 vs. 3459 MW for Unit 1, until the LEFM
system is available.
2.2.6 Administrative Procedures related to Conduct of Operations for a Multi-Unit
Site
The administrative procedures related to conduct of operations at a multi-unit Watts Bar
Site will be the same as those used for the Sequoyah Site and are contained in TVA NPG
Standard Department Procedure (OPDP-1). Requirements for shift manning are
summarized below:
2.2.6.a
A SM with an active SRO license, who is also a member of the
Operations shift crew, shall be on site at all times when fuel is in the
reactor.
2.2.6.b In addition to the SM on site, a second active licensed SRO shall be in
the control room at all times. The SM may, from time to time, act as
relief Operator for the licensed SRO assigned to the control room.
E2-24
2.2.6.c
In addition to the staffing requirements stated above, shift crew
assignments during periods of core alterations, shall include a licensed
SRO to supervise the core alterations. This SRO shall not have any other
concurrent operational duties.
2.2.6.d Additional personnel may be required on shift because of unusual plant
conditions or operational needs. The SM shall obtain the additional
personnel as necessary. Activities requiring additional personnel will not
be undertaken until the required personnel are available.
2.2.6.e
An individual fulfilling the STA function shall be assigned to each shift
and within 10 minutes of the control room when a plant is being operated
in Modes 1-4. The STA may serve more than one unit if qualified.
2.2.6.f A fire brigade of at least five members shall be maintained onsite at all
times. The fire brigade shall not include those personnel required in the
control room or those personnel necessary for the 1OCFR5O Appendix R
safe shutdown of the units. Only personnel who have satisfactorily
completed the fire fighting training required by the TVA fire protection
plan shall be assigned as fire brigade members. The members of the fire
brigade shall be designated for each shift.
2.2.6.g Deviations in shift complement may be made, provided minimum
manning and license requirements of TS are met.
2.2.6.h Operations personnel should not be shifted from one unit to another unit
without sufficient time for the individual to become familiar with its
conditions.
2.2.6.i
The following table summarizes minimum staffing requirements: Note,
this is procedural minimum staffing and not Technical Specification
minimum staffing.
• Shift Manager (SRO)
1
• Unit Supervisor (SRO)
2*
• Unit Operator (RU)
4
• Non-licensed (AUO)
8
•STA
1
*Two active-licensed SROs are required for Unit Supervisor positions and a third
active licensed SRO is required as Shift Manager.
E2-25
2.2.7 Expected Method of Rotating Personnel between Units and Re-familiarization
Training To Be Conducted Before Assuming Duty on the New Unit
Watts Bar Nuclear Plant Operations Shift Schedule is a continuous five-week rotation for
each crew—including four weeks in Plant and one week in Training. Each crew will
consist of sub-crews (for example, Crew 1A, Crew 1B, Crew 2A, Crew 2B etc.).
Management expectation is that each sub-crew will assume the shift on the opposite Unit
after every training week. “Crew lA” would assume the shift for Unit 1 for four weeks,
attend training week, assume the shift for Unit 2 for four weeks, attend training week,
assume the shift for Unit 1 for four weeks, etc. while “Crew 1 B” would assume the shift
on the opposite Unit.
E2-26
3.
Training and Qualification Plan
This training plan provides an outline of the expected scope, duration, and delivery
schedule based on the analysis of the unit differences, the Unit 2 testing and start-up
schedule, and initial license needs. Certain assumptions have been made to develop this
plan and those are discussed in section 3.2. It is expected that the training schedule and
duration discussed will be sufficient to accommodate the results of any further training
needs analysis resulting from any differences not already identified.
Unit 2 fuel load and startup have been carefully coordinated with Unit 1 refuel outages,
Unit 1 upgrade to digital controls, Simulator upgrade to digital controls, LOR differences
training for startup and the licensing dates for initial license classes. This has resulted in
a plan for all licensed operators to hold dual unit licenses. Further, with the current plan,
if there are any issues with meeting the scheduled Unit 2 fuel load and startup date, there
will be no impact on this training plan.
3.1
Training Analysis
With the design freeze recently completed, the training staff is still in the process of
analyzing unit differences, conducting formal training needs analyses, and developing the
associated training materials. As of 8/9/10, 100% of issued DCNs/EDCRs have been
reviewed. Of these, approximately 16% have been initially screened as requiring
operator training and have a completed training needs analysis that has been reviewed
and approved by a special training committee. This committee was established to review
the Training Needs Analysis documents for the Operations curriculum review committees
(CRCs).
Dedicated operations resources were used to determine required unit differences training
for Operations based on all design change notices (DCN5). This ensured that a consistent
review was performed and minimized the potential that a change might be missed and not
covered in training.
Training estimates that 10% of the total number of DCNs/EDCRs are yet to be issued.
These will be reviewed for training needs as they are issued over the next several months.
Of the DCNs/EDCRs screened as likely to require some level of operator training, 90%
are relatively minor. The other 10% of differences will require some level of operator
training. Operator impacts are detailed in Attachment 1.
This training plan is designed to be flexible in nature while still maintaining the integrity
of the overall concept of the design. As Unit 2 fuel load approaches, it is recognized that
additional differences may be identified or some design changes may occur. The
procedures and processes are in place and functioning that force any new plant changes
(Unit 1 or Unit 2) to be reviewed by training personnel for impact on operator training
E2-27
programs. This is also true for changes to setpoints, procedures, designs, technical
specifications and other changes that may occur.
The training program can accommodate any future training needs identified over and
above those currently known. The approximate number of hours is flexible, as well as
the specified hours per topic described in the plan. Watts Bar is committed to ensuring
the operators are trained and evaluated in both knowledge and skill based tasks and
activities to ensure safe operation of the current unit and new Unit 2. To this end, the unit
differences comprehensive exam will be modeled after the Watts Bar biennial exam
process for licensed operators.
3.2
Training Plan Assumptions
3.2.1
The full-scope Digital Control System (DCS) will be installed in Unit 2.
3.2.2
Unit 1 will install the feed water, pressurizer level, pressurizer pressure, and
boration control portions of the DCS in U1-RFO1 1 in 10/20 12. The Unit 1
simulator will be modified with the Unit 1 DCS controls in 01/20 12,
approximately 10 months in advance of the reference unit and about the same
time as the Unit 2 start up and power ascension.
3.2.3
The training content for unit differences training will be delivered during the
normally scheduled LOR training cycles, as well as some structured on shift job
familiarization guides and a formal qualification card (OJT/TPE).
3.2.4
Unit 2 hot functional testing begins on 10/10/11. Fuel load is scheduled for
12/17/11. Initial criticality is 01/16/12.
3.2.5
Dual-unit operator licenses will be applied for at the completion of Unit 1 to Unit
2 differences training on 9/19/11 and issued to support fuel load on 12/17/11.
3.2.6
The Licensed Operator Requalification biennial examination scheduled for
November and December 2011 will cover Unit 1 and Unit 2 topics drawn from
the sample plan. Additionally, the Unit differences will also be tested in a
comprehensive exam during the cycle 10 training week, which ends the week of
9/12/11. In addition to the comprehensive written exam in cycle 10, there will be
performance based JPM evaluations on the unit differences during cycle 10.
Weekly exams given during cycle training will also be used to evaluate operator
knowledge of the unit differences.
3.2.7
The NRC grants the waiver request for the NRC administered license examination
on Unit 2. The basis for the dual-unit license application waiver request will
include:
Completion of a company-administered written
comprehensive examination, performance based JPMs in
the plant, in the control room and completion of a formal
qualification card (OJT/TPE)
E2-28
3.3
•
Completion of a formalized job familiarization guide on the
Unit 2 differences
•
A “nearly identical” justification for the units, and
•
Results of any associated NRC training inspections that
support acceptability of the station’s training program.
Description of Training and Qualification Plan for Personnel Currently
Licensed on Unit 1
3.3.1
Licensed Operator Requalification (LOR) Training Plan Design
The 2010-2011 LOR training program is designed using a standard template of 12
training cycles, each 6 weeks in duration. To synchronize with the Unit 2 project
schedule, Cycles 5 and 6 (scheduled September through December 2010) will begin
structured plant walk down training and completion ofjob familiarization guides with the
Unit 2 Control Room and plant differences. Cycle 7 (scheduled for January and February
2011) will focus primarily on normal LOR topics and information for the Unit scheduled
refueling outage in March 2011. Cycles 8, 9, 10, and 11 (scheduled May through
October 2011) will be focused on training for common systems, unit differences, hot
functional testing, and initial criticality (see Table 2 below for details). This training
commences immediately following the April 2011 refueling outage for Unit 1, and
supports Unit 2 initial fuel load in December 2011. The training plan is also designed to
complete all Unit 2 differences training and evaluation, prior to submitting the dual unit
license applications in September 2011.
3.3.2
LOR Training Plan Summary
When dual unit license applications are submitted, in September 2011, licensed operators
with Unit 1 licenses will have received approximately 124 hours of training on the Unit 1
and Unit 2 differences. The remaining 116 hours of requalification training time for
cycles 5 through 10 will be normal Unit 1 proficiency training. Job familiarization guides
and unit differences training commence as early as September of 2010. The majority of
this training will take place between May 2011 and September 2011, after which dual
unit license applications will be submitted.
This training plan includes:
•
Training on common systems, unit differences, Unit 2 procedures and Technical
Specifications
•
Completion of a unit differences job familiarization card
•
Formal OJT and TPE Qualification cards
•
Temporarily modifying the simulator to allow demonstration of the D-3 steam
generators to include the forward and back flush hardware and software. The
associated switch and indicators on the lower right of M-3 will be installed
for use in the U2 Demonstration Load.
E2-29
•
Temporarily modifying the simulator to allow demonstration of a cold clean core
initial criticality approximating the U2 core design data.
•
Training on the Sequoyah simulator to experience the dynamic response of
Digital Feedwater Control (same vendor, same control system).
The training is designed to have several components for both knowledge and
performance training and evaluation.
3.3.2.a Early on starting in cycles 5 and 6 of LOR, which starts in September
2010, there will be classroom and job familiarization guides (JFG) on
unit differences. The intent is to have classroom training followed by in
plant and in control room walk downs.
The JFGs will be designed as a formal structured document for operators
to use as guidance in locating and understanding unit differences. Once
issued, these guides can be used on a self-paced basis, but must be
completed before dual unit license applications are submitted.
3.3.2.b Cycle 7, starting in January 2011, will focus primarily on normal LOR
topics and information for the scheduled Unit 1 refueling outage in
March 2011. Cycle 7 will also cover some of the common system “tie
in” and integration with Unit 1, which will occur during the Unit 1
outage.
3.3.2.c
Cycle 8, starting in May 2011, will be dedicated to DCS and Unit 2
differences that have been analyzed to require greater than one hour of
training based on the Training Needs Analyses performed. This training
will include hands-on practice of DCS controls and interface using the
Sequoyah simulator, the Watts Bar simulator, in plant job familiarization
guides, classroom training and OJT and TPE. This cycle includes
classroom instruction delivered by vendors and by training staff.
3.3.2.c.1
There will be vendor-supplied simulations, which will
allow operators to become familiar with the new controls as
well as demonstration on DCS capabilities. The DCS
vendor will perform hands-on operator training using an
engineering station. This training on the engineering
station will involve inputting signals into a controller and
the operator will interface with the controller. No feedback
processes will be modeled. Other vendor training will be
classroom, learning about the capabilities and operator
interface with the CRT control stations.
3.3.2.c.2
JFGs will also continue through this cycle with plant tours
following classroom lectures on system differences.
E2-30
3.3.2.c.3
Cycle 8 will utilize the WBN Unit I simulator as it will be
temporarily modified to allow for demonstration of the Unit
2 (D-3) steam generators (original plant design and
simulator model), which have slightly different procedures
and controls for warm up and start up of the steam
generators. (Unit 1 steam generators were previously
upgraded to a newer version and simulator modeling was
also upgraded). Following the demonstrations, the WBN
simulator will be returned to Unit I fidelity.
3.3.2.c.4
The Sequoyah (SQN) simulator, which is very similar to
the WBN simulator, has been upgraded to digital controls
for some major systems, such as feedwater. The SQN
simulator will be utilized to conduct part task simulations,
OJT and TPE on systems containing new digital controls.
Training includes each operator performing tasks with the
DCS systems. Performance evaluations will be conducted
this cycle on the SQN simulator in the form of formal TPE
evaluations. This cycle will also include a written exam
over the material covered during the week on unit
differences.
3.3.2.c.5
Formal OJT/TPE qualification cards will be issued during
this cycle. Some OJT and TPE will be conducted on the
SQN simulator and some will be conducted in the WBN
plant and control room. A core group of operators will be
trained and evaluated to conduct the OJT and TPE in the
plant. The formal OJT/TPE qualification cards will include
in-plant topics on Source Range/Intermediate Range
Monitors, RVLIS/ICCM displays, and Boric Acid Controls.
3.3.2.d Cycle 9, starting in June 2011, will continue with differences training by
expanding the “plant changes” lesson plan normally delivered in every
cycle, to cover any remaining unit differences or any recently identified
changes.
The WBN simulator will be used as well, with scenarios delivered using
normal Unit 1 responses and procedures. Each scenario will be
immediately followed by an instructor-led discussion of how this
scenario would differ on Unit 2, including a review of Unit 2 procedures
and technical specifications.
Unit 2 Hot Functional Testing procedures and requirements will be
covered in this cycle, as well.
E2-31
3.3.2.e
Cycle 10, starting in August 2011, will provide further training on any
procedure differences, including AOl. EOI, EP and SOT procedures. The
WBN simulator will again be utilized to run normal Unit 1 scenarios,
followed by discussion of Unit 2 specific procedure differences, as
described above for cycle 9. The WBN simulator will again be
temporarily modified to allow startup training using the Unit 2 Initial
Criticality Procedures on a simulator model that approximates the Unit 2
core design.
Cycle 10 will also include a comprehensive exam over all unit
differences. The exam will include a comprehensive written, control
room JPMs, and in-plant JPMs. Operator testing and certification on
Unit 2 will be conducted by Watts Bar staff with NRC concurrence and
will request a waiver of an NRC administered license examination for
unit 2 licenses. At the conclusion of this comprehensive exam, the
station will submit dual unit license applications for all personnel
holding a Unit 1 license at that time.
The station will administer an open book examination to test the licensed
operators’ knowledge of the new Unit 2.
o
The differences exam (written and JPMs) will only include
systems, indications, controls, and logic on Unit 2 that are
different from Unit 1.
o
The station will employ the same qualitative and quantitative
criteria for the written portion of the differences exam, including
the required sample plan.
o
The station will ensure that all multiple choice written items
adhere to the standards for plausible distracters and
psychometrics.
o
The JPMs used on the differences exam will include all of the
attributes for JPMs administered to initial license applicants, i.e.,
clear pass/fail criteria for critical steps, tolerance bands where
appropriate, etc.
3.3.2.f Additional training will be administered for Unit 2 during cycle 11 and
contains training on hot functional testing and review of fuel cycle one
core design, initial criticality procedures and start up training on Unit 2.
This will include a temporary modification to the Unit 1 simulator to
allow training on a new clean core for Unit 2 startup. When this training
is complete the WBN simulator will again be returned to Unit 1 fidelity.
Cycle 11 training will be complete in October 2011 and is after license
application submittal and before Unit 2 fuel load.
E2-32
3.3.2.g The Biennial LOR exams will be administered in cycle 12, starting in
November 2011. The exam will contain evaluation on Unit 1 and Unit 2
based on topics from the sample plan for the 2-year training cycle. This
provides an additional opportunity to ensure knowledge transfer to the
incumbent operators. Unacceptable performance on these exams will
result in the license holder being removed from active duty in
accordance with the provisions of the License Operator Training
Program Remediation and successful results on a remediation exam must
be achieved before the licensee is returned to active duty.
3.3.3
LOR Examination Impact of Planned Simulator Modifications
A basic timeline for the normally scheduled LOR simulator examinations with respect to
the installation of the simulator DCS modification is as follows:
•
12/20 1 1
LOR Simulator Exams
•
01/2012
Install Unit 1 DCS controls on Unit 1 plant-reference simulator
•
10/2012
Install DCS controls on Unit 1 during Refueling Outage
•
11/2012
LOR Simulator Exams
Analog Controls
Digital Controls
(11 months practice on digital controls)
More information concerning the simulator is contained in section 3.5.
The timeline for the differences training integrated with other key training and station
milestones is provided in Figure 1.
Table 2 provides a breakdown of the differences training into the individual LOR training
cycles.
3.4
Description of Training and Qualification Plan for Personnel in
Current and Future Initial License Classes
3.4.1
Initial License Training (ILT) Plan Design
ILT classes have been coordinated to support Unit 1 refuel outages, Unit 2 initial fuel
load and start up, Unit differences training, Simulator upgrade to DCS, and Unit 1
upgrade to DCS. Two classes will initially obtain Unit 1 licenses, and then receive
differences training. Their dual unit license applications will be submitted after
differences training is completed. Subsequent classes will receive differences training
during ILT, such that, at the NRC exam dates, they receive dual unit licenses
immediately.
E2-33
3.4.2
ILT Training Plan Summary
Note: Initial license classes are numbered with the year and month the class takes
the NRC exam, i.e., class 11-06 takes the NRC exam in June of20]].
Initial Licensing Training will continue to be conducted in accordance with TVA Nuclear
Power Group Procedures.
3.4.2.a ILT Classes 11-06 and 11-10 are scheduled for their NRC Examinations
in June 2011 and October 2011 respectively which are prior to Unit 2
fuel load in December 2011. Both classes will train and examine on the
Unit I referenced simulator and their license applications (NRC Form
398) will request a Unit 1 License. After receipt of their NRC licenses,
these students will subsequently be given the differences training
contained in the LOR plan. ILT 11-06 class will receive differences
training given to LOR through cycle 9 and will attend LOR starting cycle
10. In addition to the differences exam, ILT Class 11-06 will be
responsible for taking the Operating Exam in cycle 11 and the Biennial
Written Exam in cycle 12. ILl Class 11-10 will attend their first LOR
training in cycle 1 in 2012.
A request to waiver a NRC-administered license examination for these
operators will formally occur during a second License Application
submittal to apply for dual unit licenses. Both classes will receive all of
the differences training outlined for current incumbent operators.
Additionally, these classes will be examined on the unit differences
using the same test methodology used for the incumbent population
(comprehensive vitten exams, control room JPMs and in-plant JPMs).
The results of these exams will be presented as part of the request for
waiver of the NRC administered exam.
3.4.2.b ILT Class 12-1 1 will take their NRC Examination in November 2012;
this is after the Unit 1 reference simulator is upgraded to digital controls
in January 2012, and after Unit 1 Main Control Room (MCR) is
upgraded in October 2012. These students will be trained on Unit 1 and
Unit 2 differences during the course of their ILT class. This class will
use the DCS upgraded simulator. This class will submit License
Applications for a dual unit license.
3 .4.2.c No ILT classes will take NRC exams on the simulator during the 10month time frame that the simulator leads the changes on the plant.
E2-34
3.4.3
ILT Examination Impact of Planned Simulator Modifications
A basic timeline for the ILT simulator examinations with respect to the installation of the
simulator DCS modification is as follows:
•
06/2011
ILT Class 11-06 NRC Exam
Analog Controls
•
11/2011
ILT Class 11-10 NRC Exam
Analog Controls
•
01/2012
Install Unit 1 DCS controls on Unit 1 plant-referenced simulator
•
10/20 12
Install DCS controls on Unit 1 during Refueling Outage
•
11/2012
ILT Class 12-1 1 NRC Exam
Digital Controls
•
06/20 13
ILT Class 13-06 NRC Exam
Digital Controls
The timeline for the differences training integrated with other key training and station
milestones is provided in Figure 1.
3.5
Maintaining Simulator Alignment with the Reference Unit 1
3.5.1
Simulator Configuration Plan Design
This plan was designed to support Unit 2 fuel load and start-up, Unit 1 upgrade to DCS,
support of LOR training for unit differences training, support of LOR training following
Unit 2 start-up and support of ILT such that personnel are examining on the reference
unit simulator.
3.5.2
Simulator Configuration Plan Summary
The WBN simulator will be maintained certified as a Unit 1 Reference Simulator.
3.5.2.a In support of steam generator differences training the simulator will
temporarily be loaded with a Unit 2 steam generator model to
demonstrate the operational characteristics of the Unit 2 steam
generators. This is scheduled for cycle 8 and cycle 11 as part of the unit
differences training.
3.5.2.b In support of reactor core differences training topic the simulator will
temporarily be loaded with a Unit 2 reactor core model to demonstrate
the operational characteristics of the Unit 2 reactor core. This is
scheduled for cycle 10, in order to support Unit 2 startup training prior to
the Unit 2 license application and request for waiver of the NRC
administered Unit 2 license examination.
E2-35
3.5.2.c
Upon completion of each of these differences training topics, the
simulator will be restored to a Unit 1 referenced simulator.
3.5.2.d In preparation for Unit 1 installation of DCS for the feed water,
pressurizer level, pressurizer pressure, and boration controls in Ui
RFOI1 in October 2012, the simulator will be modified in January 2012
and will lead Unit 1 for about 10 months in the installation of these
portions of DCS. This has been standard practice in the industry to
install modifications in the simulator prior to the reference unit to allow
training on the new modifications and Watts Bar will follow this
standard practice.
At Unit 2 fuel load in December 2011, Unit 2 will be equipped with a comprehensive
digital control system (DCS). A DCS upgrade for feedwater, pressurizer and boration
controls is planned for Unit 1 in October 2012, during refueling outage Rh. The Unit 1
plant-referenced simulator will be modified in advance of the reference plant by installing
DCS in January 2012, or about 10 months ahead of the plant. Modifying the simulator on
this schedule will also provide the operators with a hands-on DCS operating simulation in
the time frame of Unit 2 power ascension testing, but after fuel-load. ILT Class 12-11
was rescheduled to ensure that the operator exam is administered on a fully aligned Unit
1 plant referenced simulator. Delaying this class for 5 months, to align with the simulator
upgrade, will not impact the number of license operators needed at Watts Bar during this
time. Modifying the simulator to DCS on this time line will result in simulator
examinations as follows:
•
06/2011
ILT Class 11-06 NRC Exam
Analog Controls
•
11/2011
ILT Class 11-10 NRC Exam
Analog Controls
•
12/20 1 1
LOR Simulator Exam
Analog Controls
•
01/2012
•
10/2012
Install Unit 1 DCS controls on Unit 1 plant-referenced simulator
Install DCS controls on Unit 1 during Refueling Outage
•
11/2012
lET Class 12-11 NRC Exam
Digital Controls
•
11/2012
LOR Simulator Exam
Digital Controls
(11 months practice on digital controls)
•
06/20 13
ILT Class 13-06 NRC Exam
Digital Controls
The timeline for the differences training integrated with other key training and station
milestones is provided in Figure 1.
Table 2 provides a breakdown of the differences training into the LOR training cycles.
E2-36
Table 2: Differences Training Scope, Duration, and Schedule
Training!
Activity
Start Date
Hours
LOR Cycle 5
9/13/10
4
Two hours of classroom followed by completion of
job familiarization guides (JFGs)
LOR Cycle 6
1 1/15/10
4
Two hours of classroom followed by structured inplant tours and continuation of JFGs.
NRC 71111.11
1 1/22/10
NRC LOR program inspection.
LOR Cycle 7
1/24/11
Ul-RFOIO Training. Will include the integration of
common system tie-ins to Unit 1 which will take
place in the Unit I refuel outage
U]RFJO
3/21/11
U1-RFOJO
LOR Cycle 8__[
Tuesday
5/9/1 1
—
Formal OJT/TPE
Qual cards issued
and continuation of
JFGs
Foxboro DCS
Vendor Training
10 hours:
Classroom and
Vendor DCS
Mockup
**
Topics
40
Wednesday
3 Hours
Classroom:
WINCISE
Incore Flux
Mapping
4 Hours
Classroom:
Common Q
(RVLIS, Core
Exit TCs,
Subcooling
Monitors)
3 Hours
Classroom:
Unit 2 Impact
on Common
Systems (i.e.
ERCW, CCS,
Control Air,
etc)
See Detailed Week Schedule below
-
Thursday
4 Hours
Classroom:
Turbine and
Secondary Plant
Changes (MSRs,
Heater Drains)
2 Hours
Classroom
Unit 2 D-3
(OSGs)
Friday
Saturday
5 Hours
Sequoyah
Simulator:
(Individual task
training)
Digital Control
Training and
Qual cards
(Hands-on
training)
5 Hours
Sequoyah
Simulator:
(Individual task
evaluations)
Digital Control
Training and
Qual Cards
(Hands-on
evaluation)
OJT on Digital
Controls
Completion of
TPE on Digital
Controls
4 Hours WBN*
Simulator
Unit 2 SG Startup
Demo and
Practice
A weekly unit differences exam will be administered
during this week with a combination of a written test
and TPE on SQN simulator.
INFO Plant
Evaluation
ILTNRC Exam
6/6/1 l
Biennial plant evaluation process
6/6/11
ILTClass#11-06
E2-37
Training!
Activity
Start Date
Hours
Topics
LOR
Cycle 9
6/27/1 1
12
The Normal Cycle of LOR will be conducted
including an ‘as found” simulator evaluation. Minor
differences between units, not addressed during LOR
Cycle 8 will be covered during an expanded LOR
Changes Lesson Plan with approximately 2 hours
dedicated to Unit 2 differences. Simulator exercises
will include an instructor-facilitated discussion of
how the scenario might have been different on Unit 2
including, any differences in Unit 2 procedures or
plant response. This cycle will have 20 hours of
simulator time scheduled with 6 hours scheduled for
discussions on Unit differences as described above.
An additional 4 hours of classroom training will be
on the Unit 2 Hot Functional Testing procedures and
requirements.
LOR
Cycle 10
8/15/11
24
The Normal cycle of LOR will be conducted with a
training session on Unit 2 procedure differences
(EOIs, AOIs, and SOIs). This will require 4 hours of
classroom time. Scenarios will be conducted on the
simulator using Unit 2 EOIs and AOIs as far as
possible and Unit 2 differences in the AOl response
will include an instructor-facilitated discussion.
Cycle 10 will require temporary modification of the
WBN simulator to allow operators to perform a
startup using the Unit 2 Initial Criticality Procedures
on a simulator model that approximates the Unit 2
core design.
The breakdown of unit differences training in this
cycle is 10 hours of simulator, 4 hours of classroom
and 10 hours for exams (written and JPMs).
A comprehensive differences exam will be given
during this week of training. The exam will be a
combination of written, control room JPMs, and
in-plant JPMs.
Unit 2
Differences
Exams will be
administered
HFT Training
Total training
hours for dual
unit license
applications
8/22/1 1
Submit 398’s
9/19/1 1
124
Unit 2 Hot Functional Testing starts 10/10/2011
8 hours total cycles 5 &6 (4 hours each in cycle 5 &
6)
40 hours in cycle 8
12 hours in cycle 9
24 hours in cycle 10 including unit 2 comprehensive
exams
Includes 30 hours to complete OJT/TPE Qual. Cards
Includes 10 hours to complete JFGs
Submit dual unit license applications
E2-38
Training!
Activity
LOR
Cycle 11
Start Date
Hours
10/3/1 1
20
Topics
Hot Functional Testing (HFT) lessons learned
Review of:
-
Unit 2 Cycle 1 core design (Unit 1 simulator)
***
-
-
JLTNRC Exam
LOR
Cycle 12
10/17/Il
FuelLoad
Initial
Criticality
Total Training
Hours for Unit
Differences
12/17/11
i/I 6/12
Unit 2 Initial criticality procedures on WBN
simulator
Unit 2 startup using D-3 SGs and forward
flush / back flush controls.
ILTClass]1-1O
BIENNIAL LOR EXAMINATIONS. This
examination will include Unit 1 and Unit 2 topics
drawn from sample plan based on the 2-year LOR
Cycle.
11/21 / 11
144
20 hours on Unit 2 Core & HFT Lessons learned
following completion of differences training and
examinations.
*
To support unit difference training, a simulator load using the original steam generator
(OSG) model will be developed to include the forward and back flush hardware and
software. The OSG model can be used for training demonstrations during unit difference
training, including the operating characteristics of the original steam generators and the
forward flush / back flush procedure.
**
The Unit 2 Foxboro contract includes 100 student-weeks of vendor supplied training.
Foxboro brings training equipment to provide hands-on operator interface training. WBN
operators and I&C technicians would attend this training, as well as select operations
training staff (train-the-trainer) and engineers.
***
When Unit 2 core data is available, the Unit 1 simulator will be temporarily modified
to model Unit 2 core data.
E2-39
—
Detailed Plant Differences
M2
52378
_____
Ml
PANEL
DCN/
EDCR
52358
2-LIC-2-3-Level
CONDS DUMP
TOCONDS
•
-
2-LIC-2-9-Level
CONDS
MAKEUP FROM
CNDS STOR
TNKS
•
-
INDICATIONS &
CONTROLS
ICS display monitor
2-MON-47-120 is
installed in place of
TR-47-000l and TR
47-0002
Condensate
Turbine
Supervisory
SYSTEM
002
SYS
#
047
E2-40
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
On Unit I these recorders (1-TR-47-0001 and l-TR-47-0002)
were abandoned and the inputs to these recorders were
provided to the plant computer system (ICS) by DCN 52846.
Future plans call for the replacement of the recorders with a
monitor like Unit 2.
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These hand stations are installed in
an area corresponding to the Unit 1 Controls.
2-M-l will contain 2 19” displays while l-M-l will contain
only 1 17” display.
This will change the way information is displayed to the
operator.
This monitor duplicates the functionality of obsolete recorders
2-TR-47-000l ‘Bearing Metal Temperature’ and 2-TR-47-0002
‘Control Start Temperature’.
DIFFERENCE
—
—
T
T
DURATION
The design differences including control system differences are annotated in the table below under the column labeled Durationas either “T
Temporary” (associated with the sequential implementation of modifications between the units or “L Long Term” (for those differences where
modifications that would resolve the differences are unscheduled or indeterminate in time.) The purpose of this table is to highlight those aspects of
the design differences that will be apparent to operators. Additional aspects of differences between the units, such as those that are apparent to
maintenance technicians primarily, are not highlighted here.
ATTACHMENT 1
2-TJC.-24-48Temp GEN
HYDROGEN
TEMP HTXS
COOLING
WATER CONT
2-TIC-24-69Temp
TURBINE OIL
TEMP
CONTROL
•
•
M2
M2
M3
52378
52378
52359
53600
Turbine
Generator
Feedwater
FW Pre-Heating
Raw
Cooling
Water
Condensate
SYSTEM
2-XI-47-2000
indicators for Main
Turbine Throttle and
governor valves,
demand and valve
limit
-
-
Hotwell Level
control transmitter
selector switches XS2-1007,-1008,1009, and -1010, will
not be used on Unit
2.
M2
52460
INDICATIONS &
CONTROLS
STOR TNKS
PANEL
DCN/
EDCR
003
047
024
002
SYS
#
E2-4 I
Hand switch 2-HS-3-45 is a 4-position switch to warm the
This will change the way information is displayed to the
operator.
Unit 1 DCN 52623A replaces obsolete Throttle and Governor
Valve indications on 1-XX-47-2000 with indicators made by
Yokogawa, 2-XI-47-2000 indicators are made by
Westinghouse.
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
Unit 2 does not plan to install these level switches nor manual
switches (which transfer between Zone A and Zone C).
Software will select the best signal for control and alarms on
Unit 2 so no operator actions are required for a failed
instrument.
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These hand stations are installed in
an area corresponding to the Unit 1 Controls.
Unit 1 has level switches LS212A, 12B, 1009A, and 1009B
Installed to signal annunciator XS553A-45D “HOTWELL
HI/LO LEVEL ALARM.”
DIFFERENCE
L
L
L
DURATION
PANEL
M3
M3
DCN/
EDCR
52360
53217
52360
52378
52360
2-LIC-3-233
2-LIC-3-234
.
.
are eliminated from
panel 2-M-3 while
they remain on Unit
1.
2-LIC-3-232
.
Main Feedwater
Pumps Stop Valve
hand switches 2HS46-13A and 2-HS46-40 are smaller
than their Unit 1
counterparts.
NIS bias controllers
• 2-LIC-3-23 1
INDICATIONS &
CONTROLS
Flush Selector HS-345 differs between
Unit 1 and Unit 2.
Status light box 2XX-3 -235 retains
additional lights
related to back
flushing operations
on the steam
generators.
Feedwater
Feedwater
SYSTEM
003
003
SYS
#
E2-42
Unit 2 will exhibit increased fault tolerance with reduced
operator actions.
Nuclear power level setpoint controllers will not have a
hand/auto station on Unit 2. On Unit 1, a single channel of NIS
power is used to determine the setpoint for each loop. On Unit
2, the second highest of the 4 channels will be used (change
will be duplicated on Unit 1 when the digital feedwater project
is completed).
On Unit 1 a single channel of NIS power is used to determine
the setpoint for each loop. On Unit 2, the Foxboro I/A control
system will select the second highest of the four channels of
NIS power.
This will not have an impact on operator actions.
Unit 2 will require additional actions in the SOIs during SG
startup.
The smaller hand switches are necessary in order to fit the
larger Foxboro I/A controllers in the same layout
configuration.
main feedwater lines through forward and back flush
operations. The Unit 1 steam generators were upgraded which
eliminated the need for back flush operations; therefore, I -HS
3-45 is a two-position switch without the back flush operation
mode. The Unit 2 Steam Generators remain a Model D3. As
such, the need for Feedwater Preheat, and forward and back
flush capabilities remain in Unit 2. On Unit 2 the solenoids
FSV-3-350, 48, 900 and 1030, are required to facilitate the
heat up, forward and back flush operations.
DIFFERENCE
T
T
L
DURATION
M3
M3
M4
52378
52361
PANEL
DCN/
EDCR
52378
•
2-PIC-1-33-Main
Steam 48” HDR
Press Control
‘
MFPT S I’ eed
Controls 2-SIC46-20 20A 20B
•
‘
FW Pump Flow
Controllers 2FIC-3-70, 84,
208
•
STM GEN FW
Inlet Bypass
Valve Controls 2FIC-3-35A, 48A,
90A, 103A
INDICATIONS &
CONTROLS
•
STM GEN FW
Inlet Flow
Controllers 2FIC-3-35, 48, 90,
103
Main Steam
Main Feed
Pump
Controls
Feedwater
SYSTEM
001
046
SYS
#
003
E2-43
DCS uses the median signal from three (3) redundant pressure
transmitters as input to the control function, the process
parameter displayed on the pressure indicator P1-1-33, which
will be fed from the DCS. The indicator will always display
This changes the method in which the operator interfaces with
the control and increases fault tolerance. (Reference Section
2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
.
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
Feedwater Pump Speed control (PC-46-20): On Unit 1 a single
transmitter is used for steam header pressure and feedwater
header pressure; on Unit 2 there will be a median select on
three transmitters for each of these signals.
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
DIFFERENCE
T
T
T
DURATION
PANEL
M4
M4
DCN/
EDCR
52361
52361
2-HIC-15-43STM GEN
Blowdown Flow
Control
2-LIC-68-339RCSPRZR
LEVEL
•
•
2-PIC-68-340DRCS PRZR
LOOP 1 PRESS
•
ESS
2-PIC-68-340B-
•
LOOP
2-PIC-68-340ARCS PRZR
(Relief Press)
•
INDICATIONS &
CONTROLS
SG
Blowdown
Pressurizer
Level and
Pressure
SYSTEM
015
068
SYS
#
_____
E2-44
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
This changes the method in which the operator interfaces with
the control and increases fault tolerance. (Reference Section
2.2.4)
This changes the method in which the operator interfaces with
the control and increases fault tolerance. (Reference Section
2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
Turbine Impulse Pressure: On Unit 1 a single transmitter is
used as input for rod control and a separate for steam dump; on
Unit 2 there will be a median select of three transmitters. Unit
2 will have a different configuration for the turbine load signal
(inlet) but the term turbine impulse pressure is still used.
the value that is being used for control at all times.
DIFFERENCE
L
T
DURATION
______
M4
M4
52361
M4
PANEL
52361
54986
DCN/
EDCR
52361
•
Steam Generator
1-4 Feedwater
Inlet Flow XS-335D,_-48D,_90D,
-
Transfer switches
• Steam Generator
1-4 Main Steam
Header Flow XS1-3D, -1OD,
21D, and 28D
-
INDICATIONS &
CONTROLS
Steam Generator
Blow Down hand
switches 2-HS-17/181, 14/182,
25/183 and 3 2/184
and the indicating
lights for these
switches are oriented
in different
configuration than on
Unit 1.
Steam Generator
PORV’s SG Main
STM HDR Press
Control 2-PlC-i -6A,
13A, 24A, 31A
Main Steam
Main Steam
Main Steam
SYSTEM
001
001
SYS
#
001
E2-45
.
Visual graphics provided for the operator on the new video
monitors on 2-M-19A and 2-M-19B provide indication of the
status of those signals and provide the capability to transfer
control for maintenance if necessary. As a result the analog
selector switches are not required.
This changes the method in which the operator interfaces with
the control and increases fault tolerance. (Reference Section
2.2.4)
The new DCS will perform the Main Steam Header Flow and
Feedwater Inlet Flow channel selector switch functions.
On Unit 1 these ioops have a single pressure transmitter as
input; on Unit 2 there will be a median select of three
transmitters.
Unit 2 controls are in same general area of the panel with a
modified layout.
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit I Controls.
On Unit 1 these hand switches and their associated indicating
lights are arranged in a row. On Unit 2 these hand switches and
their associated indicating lights are arranged with two
switches in one row with the other two switches mounted
directly above. This relocation was necessary due to the
increased mounting area needed to install four Foxboro I/A
controllers located adjacent to the Steam Generator Blow
Down hand switches.
DIFFERENCE
T
T
T
DURATION
M4
M4
52361
52343
52427
52408
PANEL
DCN/
EDCR
.
Anticipated
Transient Without
Scram (ATWS)
Mitigating System
Actuating Circuitry
(AMSAC)
Motor Driven
Auxiliary Feedwater
pump discharge
pressure controllers
2-PDIC-3-122A and
1 32A have been
replaced with
Foxboro SPEC 200
controllers.
will not be installed
on Unit 2
Temperature
recorder 2-TR-94-.
101, switch 2-XS-68101 and RVLIS
indicator 2-XI-68100 will not be
installed on 2-M-4.
.
INDICATIONS &
CONTROLS
and -1 03D
AMSAC
AFW
Incore
Neutron
Monitoring,
RVLIS
SYSTEM
003
003
094,
068
SYS
#
E2.-46
For AMSAC, these are acceptable engineering differences
because pressure indicated with 2-PT-i -314 and -315 will still
This changes the method in which the operator interfaces with
the control.
Unit 2 AMSAC will have a 40% power setpoint to arm
AMSAC. The Unit 2 pressure transmitters, which have a 03000 psia range instead of 0-1000 psia, will read the first stage
pressure or the inlet pressure instead of impulse chamber
pressure as done in Unit 1.
Unit 2 utilizes the Foxboro SPEC 200 for the entire ioops
including Indication in MCR, Annunciation, and feeds to
AMSAC for loops 2-LPL-3-172, 2-LPL-3-173, 2-LPL-3- 174,
and 2-LPL-3-175.
Additionally, Unit 1 utilizes the Foxboro SPEC 200 only for
the Motor and Turbine Driven AFW control portion of loops.
These controllers perform the same function as the components
used in Unit 1. On Unit 1 these components are GEMAC
controllers.
This will change the way information is displayed to the
operator.
The new COMMON Q display 2-MON-68-lOO will perform
these functions for Unit 2.
Unit 2 will exhibit increased fault tolerance with reduced
operator actions.
DIFFERENCE
L
T
L
DURATION
PANEL
M4
MS
MS
DCN/
EDCR
53756
52378
52378
.
Pressurizer pressure
control (PIC-68340):
.
2-XS-68-340DRCS PRZR
PRESS has Auto
.
.
2-XS-68-339BPRZR LVL REC
Channel Sel is
eliminated
Reactor
Coolant
Reactor
Coolant
Pressurizer level
control (LIC-68339):
.
2-XS-68-339EPRZR LVL
CONT Channel
Sel has Auto
Position
.
068
Reactor
Vessel Head
Vent
Reactor Vessel Head
Vent Throttle Valve
controllers 2-HIC68-3 96 and 2-HIC68-3 97 have been
replaced with
Foxboro SPEC 200
controllers.
068
068
SYS
#
SYSTEM
INDICATIONS &
CONTROLS
.
.
.
E2-47
On Unit 1 there is a second selector switch (XS-68-340B) that
On Unit 1 there is a selector switch (XS-68-340D) to select the
pressure transmitter used as input. On Unit 2 a similar switch
will be provided, and it will have an additional position,
“auto”, which will allow the software to use a median select.
Unit 2 will exhibit increased fault tolerance with reduced
operator actions.
.
On Unit 1 there is a second selector switch (XS-68-339B) that
selects the transmitter signal going to the recorder; this switch
is eliminated on Unit 2 and the signal used for control will go
to the recorder.
On Unit 1 there is a selector switch (XS-68-339E) to select the
level transmitter used as input. On Unit 2 a similar switch will
be provided, and it will have an additional position, “auto”,
which will allow the software to use a median select.
This changes the method in which the operator interfaces with
the control and increases fault tolerance.
This will not have an impact on operator actions.
These controllers perform the same function as the
Westinghouse controllers used in Unit 1.
correlate with reactor power and still have a setpoint indicative
of 40% reactor power.
DIFFERENCE
T
T
T
DURATION
PANEL
M5
MS
DCN/
EDCR
52378
52690
2-HIC-62-89ACharging Flow
Control Valve
2-HIC-62-93ACharging Header
Flow Control
.
•
UNIT 2
RECORDERS
• 2-PR-068-0340
RCS Pressurizer
Pressure
• 2-TR-068-0002A
RCS Overpower!
Overtemperature
• 2-TR-068-0002B
RCS Tave/Tref
• 2-LR-068-0339
RCS Pressurizer
Level
• 2-PR-068-0063
RCS Wide Range
2-HIC-62-56AExcess Letdown
Flow Control
2-XS-68-340BRCS PRZR
PRESS is
eliminated
•
.
INDICATIONS &
CONTROLS
Position
Reactor
Coolant
Chemical
and Volume
Control
SYSTEM
068
062
SYS
#
.
.
E2-48
This will change the way information is displayed to the
operator.
Unit 2 will have Paperless digital recorders. Unit 1 is replacing
these recorders as they fail.
.
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
Unit 2 will exhibit increased fault tolerance with reduced
operator actions.
selects the transmitter signal going to the recorder; this switch
is eliminated on Unit 2 and the signal used for control will go
to the recorder.
DIFFERENCE
T
T
DURATION
PANEL
M6
M6
DCN/
EDCR
52378
52378
2-HIC-.74-28ARHRHTEXCH
B Flow Control
2-HIC-74-32ARHR HT EXCH
A and B BPS
Flow Control
Valve
•
2-LIC-62-130A.
Volume Control
Tank Level
Indicating
Controller
•
•
2-HIC-62-83ARHR Letdown
Flow Control
•
2-HIC-74-16ARHR HT EXCH
A Flow Control
2-HIC-62-78ALetdown HT
EXCH Outlet
Temp
•
•
2-HIC-62-81ALetdown HT
EXCH Press
CONT
•
INDICATIONS &
CONTROLS
Pressure
074
062
Chemical
and Volume
Control
Residual
Heat
Removal
SYS
#
SYSTEM
.
E2-49
.
.
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
This changes the method in which the operator interfaces with
the control and increases fault tolerance. (Reference Section
2.2.4)
Volume Control Tank level (LIC-62-130A): On Unit 1 this
controller has a single level transmitter as input; on Unit 2 it
will be the average of two level transmitters.
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
DIFFERENCE
T
T
DURATION
M6
M6
M6
52363
52363
52363
DCN/ PANEL
EDCR
52363 M6
—
-
Cold Leg
Accumulators Level
and Pressure
indicators (LI-63
129, -119, -109, -99,
-89, -81, -82, and -60
and P1-63-128, -126,
-108, -106, -88, 86,61, and -61) are
located below the
new Common Q
driver RVLIS
ICCM monitor
Incore flux
temperature recorder
TR-94- 102 is not
installed on panel 2M-6.
The RVLIS display
XI-68-1 10 and its
keypadXS-68-111
on panel 1 -M-6 are
replaced with 2MON-68-1 10
2-HIC-62-23 7-Boric
Acid Tank B Recirc
Flow
2-HS-62-140AHoldup Tanks Recirc
INDICATIONS &
CONTROLS
2-HIC-63-65A-SIS
ACCUM TANK N2
HDR VENT VALVE
Chemical
and Volume
Control
Reactor
Coolant
Incore
Neutron
Monitoring
Safety
Injection
SYSTEM
062
068
SYS
#
063
Q 2-MON-68-l 10.
E2-50
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
This will change the way information is displayed to the
operator.
Common Q monitor 2-MON-68-110 replaces the functions of
XI-68-l 10 and XS-68-l 11.
This will change the way information is displayed to the
operator.
Data points will be included on Common
This will change the way information is displayed to the
operator.
The Cold Leg Accumulator group of indicators are located
below the new Common-Q RVL1S-ICCM monitor (2-MON68-110) on panel 2-M-6. They are located above RVL1S
display (1-XI-68-110) on 1-M-6. This was done to fit the new
15-inch Common-Q display in the layout area.
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
The Unit 2 operator interface Manual/Auto hand control
stations are digital control stations replacing the analog
controllers used in Unit 1. These M/A hand stations are
installed in an area corresponding to the Unit 1 Controls.
DIFFERENCE
T
L
L
L
DURATION
PANEL
M6
DCN/
EDCR
52343
Annunciator window
box XA-55-6F
(windows 145D,
146D, and 147D)
—
INDICATIONS &
CONTROLS
Pump Control
2-HS-62- 1 40BHoldup Tanks Recirc
Pump Control
2-FC-62-139-Boric
Acid Flow To
Blender Control
2-FC-62-142-PMW
Flow Cont To Boric
Acid Blender
Annunciator
SYSTEM
055
SYS
#
E2-51
In the Unit 2 annunciator window box XA-55-6F (windows
145D, 146D, and 147D), annunciation for fuses blown in ACR
PNLs 2-L-1 1A, 2-L-1 lB and 2-L-10 will be combined into
window 146D and will have the re-flash function. In Unit 2,
window 147D will be used for power failure in PNL 2-L-381A
CMPTA, B or C and will have the re-flash function. Unit 2
window 145D will be a spare window.
This will change the way information is displayed to the
operator.
Functionally similar batch counters with digital displays will
replace the batch counters. Two displays will be included, as it
was determined that a third counter is not used. Upgrade of the
boric acid batch counters 2-FQ-62-139 and 2-FQ-62-142 to the
new Foxboro I/A digital control system necessitates providing
an electronic audible clicking device (speaker with digital
amplifier) 2-XA-62-139C inside the cabinet. The electronic
clicker mimics the mechanical clicking sounds generated by
the analog Foxboro H-Tine controllers used on panel 1 -M-6.
The audible clicking sounds alert the Operator to the rate of
fluid flow. The clicking device is driven by the Foxboro I/A
system.
The primary water flow controller’s setpoint will display in
gpm. The boric acid flow controller will have an indicator that
will indicate if the displayed setpoint is in gpm or ppm. Ppm
will be used for the automatic makeup mode; gpm will be used
for the other modes.
For the Boric Acid blending system flow controllers, the
setpoint display will be a digital indicator.
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
DIFFERENCE
L
DURATION
AN Panel 2-XA-556F Deletes ANN
Windows 145A &
146A TRN AJB
R127/128/143 &
RI 30/131/140
windows
UNIT 2
RECORDERS
.
2-PDR-030-0 133
Containment
Pressure Narrow
Range PSID
.
2-PR-030-0045
Containment
Pressure Wide
Range
Ventilation and Ice
Condenser
Indications and
Controls
M6
M6
M9
52376
52427
52690
52366
-
INDICATIONS &
CONTROLS
PANEL
DCN/
EDCR
Ventilation,
Ice
Condenser
Ventilation
Annunciator
SYSTEM
30,
61
030
055
SYS
#
E2-52
The following Unit-i components are located only on Unit-i
Panei 1-M-9 & corresponding Unit-2 components do not exist:
l-XI-030-0 136, l-XI-03 0-0139, l-XI-03 0-01 59, l-XI-030-0 162,
l-XI-03 0-0274, l-XI-03 0-0278, l-XI-03 1-0342, l-XI-03 1-0343,
l-XI-03 0-0103, l-XI-03 0-0102, l-XI-03 1-00350, i -XI-03 10365, 1-HS-030-0103A, 1-HS-030-01 02A, 1 -HS-030-Oi 06, 1HS-030-0086, 1-HS-030-0i 07, 1-HS-030-0087, 1 -HS-030-
Only Unit I Panel contains the controls for chillers and fans
that are common to both Units. These controls have been in
use since Unit 1 startup. This is part of the original design.
This will not have an impact on operator actions.
This will change the way information is displayed to the
operator.
This will change the way information is displayed to the
operator.
Unit 2 will have Paperiess digital recorders. Unit 1 is replacing
these recorders as they fail.
Due to the replacement safety related BOP instrument loops
and the installation equipment in new panels 2-R-129 (Train
A) and -132 (Train B), several loss of power alarms are no
longer needed.
This will change the way infonnation is displayed to the
operator.
DIFFERENCE
L
T
T
DURATION
PANEL
M10
DCN/
EDCR
52694
53246
Unit 2 Train A
Switches will be
detrained and at the
local panel a Meggitt
supplied PLC
Control and Display
Assembly used for
the Hydrogen
The Train B
Hydrogen Analyzer
hand switches and
indicators are being
removed.
XI-043-0200A, XI043-0210A, XI-0430210, H21-043-0210,
HS-043 -0207B,
0208B, 0207A,
0208A, &02 1 OA
INDICATIONS &
CONTROLS
Post
Accident
Sampling
SYSTEM
043
SYS
E2-53
Unit 2 will have fewer switches and indicators on the control
Unit 2 non-i E, commercial grade Hydrogen Analyzer will
perform the same analysis function as Unit 1 IE, Train A
Hydrogen Analyzer. There is no Unit 2 redundant Hydrogen
Analyzer as there is on Unit 1 (Train B).
52367. Integrated Computer System (ICS) point CI000A will
be utilized and point Cl 001 A will be spared. Annunciator
Window 5C-103C will receive one input from 2-H2AN-043200.
The Delphi equipment installed on Unit 1 is obsolete and no
longer available and will be replaced with a Meggitt supplied
remote PLC Control and Display Assembly used for the
Hydrogen Analyzer.
The following Unit-2 associated components are located on
Unit-l Panel l-M-9:
2-XI-03 0-0104, 2-XI-03 0-0105, 2-HS-03 0-01 04A, 2-HS-03 001 05A, 2-HS-030-0 108, 2-HS-030-002 I, 2-HS-030-0i 09, 2HS-030-0022, 2-HS-030-0270, 2-HS-030-0271, 2-HS-0300275, 2-HS-03 0-0272, 2-HS-030-0276, 2-XI-030-0274, 2-HS030-0274A, 2-HS-030-0278A, 2-XI-030-0278
Unit 2 will have one train of Hydrogen Analyzers and 4
containment isolation valves. Unit 1 has 2 trains of Hydrogen
Analyzers and 8 isolation valves. Unit 2 will have 2 calibration
gas bottles versus 6 bottles for Unit 1.
,
0158, 1 -HS-030-0269, 1 -HS-030-0 160, 1 -HS-030-01 66, 1-HS030-0161, I-HS-030-0167, 1-XT-030-01 59, 1 -HS-030-01 59A,
1 -HS-03 0-01 62A, l-XI-03 0-0162 l-XI-06 1 -0089A, l-XI-06 10089B, 1 -XI-061 -0089C, 1 -XJ-06 1 -0089D, l-XI-061 -0089E,
I -XI-06 1 -0089F
DIFFERENCE
L
DURATION
PANEL
Ml 0
M10
M10
M10
Mu
DCN/
EDCR
52329
52367
53920
53559
52367
52367
53196
52368
Generator Core
Condition Monitor
Display 2-XI-0350060 will be replaced
with ICS
Post Accident
Sampling System
Hand Switches are
removed
HS-043-250A, 309A,
287A, 31 8A, 342A,
341A,307A, &
325A
ICE Condenser
Recorder is being
removed TR-06 10138
INDICATIONS &
CONTROLS
Analyzer
Hydrogen
Recombiners
Controls
H2C-083-0001,
H2C-083-0002 are
not present on Unit 2
Unit 2 PASS
hardware will be
removed.
Generator
Cooling
ICE
Condenser
Post
Accident
Sampling
Post
Accident
Sampling
Hydrogen
Recombinati
on
SYSTEM
061
061
043
043
083
SYS
#
E2-54
This will change the way information is displayed to the
operator.
2-M-11 will have all components removed, 1-M-1 1
components still exist. Unit 1 Generator Core Condition
Monitor Display, on Panel l-M-1l, will be replaced by ICS in
Unit 1, 5-year plan to replace the components.
There will be a recorder at the seal table which will be used to
multiplex and provide backup indication
Unit 2 will not have a Control Room ice bed temp recorder.
The Ice Bed Temperatures will be monitored using the
computer indications (ICS).
Unit 2 will have reduced operator actions.
Unit 2 will have reduced operator actions.
Post Accident Sampling System Hand Switches HS-043-250A,
HS-043 -309A, HS-043-287A, HS-043-3 1 8A, HS-043 -342A,
HS-043-341 A, HS-043-307A, and HS-043-325A are not
required because PASS is no longer required.
Unit 2 is deleting PASS hardware. Unit 1 has removed PASS
from TS, but hardware is still in place.
Unit 2 will have reduced operator actions.
room panel. This will not have an impact on operator actions.
The Unit 2 hydrogen recombiners have been abandoned in
place. Accordingly, the Controls in Panel 2-M- 10, which are
part of this abandoned system, are not required.
DIFFERENCE
L
T
T
DURATION
2-RM-90-121
Radiation Monitors
replaced with Digital
Units
• 2- RM-90-002
Personal Access
Area Monitor
(Personnel
Airlock)
• 2- RM-90-059
Upper Cntmt
Area Monitor
(Hatch)
• 2- RM-90-060
Upper Cntmt
Area Monitor
(Airlock)
• 2- RM-90-061
Incore
Instrumentation
Room
• 2- RM-90-106
Lower Cntmt Air
2- RM-90-1 12
Upper Cntmt Air
• 2-RM-90-119
Condenser
Vacuum Exhaust
• 2- RM-90-120
Steam Generator
Building Effluent
M12
52340
52341
53037
•
INDICATIONS &
CONTROLS
PANEL
DCN/
EDCR
Radiation
Monitor
SYSTEM
__________
090
SYS
#
____
DIFFERENCE
E2-55
This will change the way information is displayed to the
operator.
This will change the way information is displayed to the
operator.
Unit 1 is Analog. Unit 2 is Digital. The new ratemeters have
the same function (indicated value, alarms, display ranges,
etc.) to the ones currently installed in Unit 1.
_________
T
DURATION
PANEL
M13
DCN/
EDCR
52421
2-Nl-92-131-D
Channel 1 Source
Range Signal
Processor
2-Nl-92-132-E
Channel 2 Source
Range Signal
Processor
2-N1-92-133-D
Channel 1
Shutdown
Monitor
2-Nl-92-134-E
Channel 2
Shutdown
Monitor
2-NI-92-135-D
Channel I
intermediate
Range Signal
Processor
2-Nl-92-136-E
Channel 2
Intermediate
Range Signal
Processor
•
•
•
•
•
•
INDICATIONS &
CONTROLS
Steam Generator
Building Effluent
SYS
#
092
SYSTEM
Excore
Neutron
Monitoring
E2-56
Unit 1 currently has the Gamma-Metrics source intermediate
range system model RCS-300. Watts Bar Unit 2 will receive
the new 300i NFMS (neutron flux monitoring system).
Source Range/Intermediate Range Signal Processor
Improvements:
-The source and intermediate signal processors come with
upgraded bar graph liquid crystal displays, as the Unit 1 analog
meters are obsolete.
-In Unit 1, the Source and Intermediate range signal processors
have “Counts per second” or “Percent power level” displays,
respectively. In Unit 2 source range signal processors, the
vendor is including indication for both neutron level in counts
per second, and decades per minute on the instrument rack.
The intermediate range signal processors will include not only
decades per minute, but will also indicate percent power on the
instrument rack.
The selector knobs for Unit 2 on the intermediate range signal
processor are set up differently than on Unit 1. There are a total
of 3 dials on Unit 1 including level trip, adjust, and operation
selector. On Unit 2 there are a total of 5 knobs including test
selector and output selector in addition to those previously
mentioned. The selector knobs for Unit 2 on the source range
signal processor are set up differently than on Unit 1. There are
a total of 3 dials on Unit 1 including level trip, operation
selector, and high flux at shutdown. On Unit 2 there are a total
of 4 knobs including level test and output selector in addition
to level trip and high flux at shutdown. The controls and
indications on the instrument rack are operated by
Instrumentation and Controls during maintenance and testing
of the source range and intermediate range monitors. The
DIFFERENCE
L
DURATION
PANEL
M14,
M16,
Ml 9A
&B
DCN/
EDCR
52454
Center Work Desk
Area and Displays
INDICATIONS &
CONTROLS
SYSTEM
SYS
#
E2-57
This will change the way information is displayed to the
operator.
The differences in the Unit 1 and Unit 2 workstation desks are
primarily those of a cosmetic nature. The work area “footprint”
is consistent between units and provides for the same number
of operators in the seating arrangement. The work area and
work surface of the Unit 2 consoles is improved over that of
Unit 1 in that the Unit 2 layout provides a slightly larger
dimension between work surfaces.
The wide range signal processor in panel 2-L-1O will be in a
different location than in Unit 1. The backup source range
drawer is being removed from 2-L-1O due to obsolescence, and
the wide range signal processor will be mounted in its place.
In Unit 1 due to cable routing, there was a potential for both
channels to be functionally disabled due to a possible appendix
R event. To address this, Unit 1 provided the ability to remove
the wide range signal processor from the auxiliary control
room, and take the device down to get signal directly from the
channel 1 optical isolator, and get power from channel 2
amplifier. Unit 2 will route cables for the device in such a way
that appendix R will not be a concern.
The shutdown monitor on the Unit 2 side will not contain an
alarm reset button, which was used to manually disable the
alarm during the drawer latching process. The alarm reset
function is now obsolete as this feature can be handled at the
annunciator.
scales and indicators on 2-M-4, which are used by the
operators during startup and operation, are unchanged except
that the displays change from analog to digital indication.
DIFFERENCE
T
DURATION
SYS
#
032
SYSTEM
Compressed
Air
Various
INDICATIONS &
CONTROLS
2-M-15 will have 3
control switches that
have the different
numbers than Unit 1
switches on 1-M15,
but perform the same
functions.
MiS Alarm inputs
and common
equipment supplied
by Unit 1 Only.
PANEL
M15
MIS
DCN/
EDCR
52370
52385
E2-58
This will not have an impact on operator actions.
The design of the unit 2 “motor trip-out alarm” (main control
board disagreement alarm) alerts the operator whenever a
control switch’s demanded position does not agree with
devices. The motor trip annunciation signal for Condenser
Circulating Water pumps is on panel 2-M-l5.
Other differences are that 1 -M- 15 contains common “Unit
designator 0” equipment that has been used since Unit 1
startup.
There are no MCR controls/indications for cooling tower
draining and blow down required for Panel 2-M- 15.
Reactor Bldg Train A, B, and Non-Essential Isolation (Aux
Air) Hand switches that are located on Panel 1 -M- 15 have a
different number than their equivalent control switch on panel
2-M-15. HS-32-80A, HS-32-102A, & HS-32- 1 1OA on Unit 1
are identified differently from HS-32-81A, HS-32-103A, &
HS-32-l 1 1A on Unit 2, although they perform the same
functions. This is part of the original design.
This will change the way information is displayed to the
operator.
There is a difference between Unit 1 and Unit 2 in the number,
type, use, and arrangement of displays/monitors. Unit 2
displays (20” LCD flat panel monitors) are modern in nature
and sized to accommodate the functions of ICS, Foxboro 1/A,
and alarm monitoring. Unit 1 displays consist of CRTs housed
within turrets for rotating. The unit 2 displays are “back to
back” to accomplish the same effect as the turrets by providing
information to the operator within the workstation seating area
or outside perimeter.
DIFFERENCE
L
L
DURATION
SYS
#
094
SYSTEM
Incore
Monitoring
System
INDICATIONS &
CONTROLS
Unit 2 uses
W1NCISE for
functions performed
by Unit I Moveable
Incore Detectors and
associated lncore
Thermocouples
PANEL
M18
DCN/
EDCR
52371
52815
52321
E2-59
This will change the way information is displayed to the
operator.
Each IITA also houses a Core Exit Thermocouple (CET). The
CET contained in each IITA is positioned to provide a
measurement of the reactor coolant temperature at the top of
the active fuel of the host fuel assembly thus providing a
component measure of the core exit temperature. The CET
measurements are for use by the Post Accident Monitoring
System (PAMS), and are not used by the WINCISE System to
measure the core power distribution.
The following shared items are located on Unit 1 panel and are
not duplicated on Unit 2:
Fire pumps 1-A-A, lB-B, 2A-A &2B-B
Raw Cooling Water Pumps A, B, C, D, E, F &G
Component Cooling Pumps lA-A, lB-B, 2A-A, 2B-B, & C-S
Essential Raw Cooling Water Pumps A-A, B-A, C-A, D-A, E
B, F-B, 0-B &H-B
Unit-2 side panel 2-M-18 will have its front panel modules
removed. The replacement for the Moveable Incore Detector
System housed in panel 2-M-18 is the WTNCISE System.
Watts Bar Unit 2 uses Incore Instrument Thimble Assemblies
(ITTA), containing five self-powered neutron detectors (SPD),
to continuously measure the three-dimensional (3-D) core
power distribution. The SPDs are distributed both axially and
radially within the reactor core to provide continuous
measurements of signals directly proportional to the neutron
flux present around each SPD element. The measured SPD
signals are processed to be suitable for use by the BEACON
TSMTM Power Distribution Monitoring System (PDMS) to
generate continuous 3-D measurements of the reactor core
power distribution.
DIFFERENCE
L
DURATION
52338
M-30
DCN/ PANEL
EDCR
52315 M2 1
53673
52839
SYS
#
055
090
Annunciator
Radiation
Radiation Monitors
SYSTEM
INDICATIONS &
CONTROLS
Unit 2 Annunciator
system will be an
upgraded model
E2-60
Unit 1 is Analog. Unit 2 is Digital. The new ratemeters have
This will change the way information is displayed to the
operator and increases fault tolerance.
Unit 1 XA-55-15A and XA-55-15B will be replaced on Unit 2
with XA-55-15A. The pertinent alarms from Unit 1 A and B
boxes will be displayed on the 2 XA-55-lSAbox.
Unit 2 has all MCR annunciator loads from M2 1 and the Unit
2 annunciator Inverter. All Unit 2 Annunciator Ronan supplied
equipment will be powered from the Unit 2 annunciator
Inverter. Unit 1 remotes are powered from other plant power
sources.
Unit 2 has redundancy against single failure designed in with
the exceptions of the conductor from the redundant Xl lOs and
the redundant bulbs and the annunciator Inverter. The Inverter
will have a bypass switch that isolates and de-energizes the
Inverter cabinet when In BYPASS.
Windows 135 A, B and D for the annunciator inverter will be
different when DCN 52389 is implemented. All Annunciator
power/failure alarms will actuate 135A and 135B/D will be
spared on Unit 2.
Unit 2 has a special operator “end to end” channels test feature.
Unit 1 does not.
Unit 2 annunciators will be Windows based. Unit 1 remains
DOS based. Disable/Enable of alarms will be different on Unit
2 than Unit 1. Unit 2 also has 2 redundant independent
channels of Annunciation.
DIFFERENCE
T
DURATION
DCN/
EDCR
52340
52342
PANEL
INDICATIONS &
CONTROLS
replaced with Digital
Units
• 2-RM-90-255
Condenser
Vacuum Exhaust
Low Range
• 2-RM-90-256
Condenser
Vacuum Exhaust
High Range
• 2-RM-90-271
Upper Cntmt
High Range
• 2-RM-90-272
Upper Cntmt
High Range
• 2-RM-90-273
Lower Cntmt
High Range
• 2-RM-90-274
Lower Cntmt
High Range
• 2-RM-90-421
Main Steam Line
Post Accident
Monitor
• 2-RM-90-422
Main Steam Line
Post Accident
Monitor
• 2-RM-90-423
Main Steam Line
Post Accident
Monitoring
SYSTEM
SYS
#
E2-61
This will change the way information is displayed to the
operator.
The configuration of Post Accident Monitor 2-RM-90-404 will
not be used in Unit 2. The replacement device for 2-RM-90404 will consist of two detectors. 2-RM-90-255 will be a
Geiger-Mueller Tube detector that will monitor the mid range
radiation levels. 2-RM-90-256 will use high range Ionization
chamber detector that will monitor the high range radiation
levels.
the same function (indicated value, alarms, display ranges,
etc.) to the ones currently installed in Unit 1.
DIFFERENCE
T
DURATION
SYS
#
090
001
062
063
074
SYSTEM
Radiation
Monitoring
Main Steam
CVCS
ECCS
RHR
Various
INDICATIONS &
CONTROLS
Monitor
.
2-RM-90-424
Main Steam Line
Post Accident
Monitor
Condenser Vacuum
Exhaust Monitor
RM-90-450 will be
removed on Unit 2
Auxiliary Control
Room Controllers
New hand stations
and instruments at 2L-1 1A, 2-L-1 lB
AND 2-L-l0
Auxiliary Control
PANEL
M31
ACR
ACR
DCN/
EDCR
52354
52671
52356
E2-62
This changes the method in which the operator interfaces with
the control. (Reference Section 2.2.4)
XS-30-90 the array of switches on 2-L-l IA are on opposite
This will not have an impact on operator actions.
Unit 2 will replace auxiliary control room non-safety-related
instrument loops with new Foxboro I/A in panels.
ACR Controllers
2-HIC-62-89C-CHRG HDR FLOW CNTL
2-HIC-62-56C-EXCESS LTDN FLOW
2-HIC-74-16C-RHR HX A OUTL CNTL
2-HIC-74-32C-RHR HX A/B BYPASS
2-HIC-62-83C-RHR LTDN FLOW CNTL
2-PIC-1-6C-SG 1 PORV CNTL
2-PIC-1-24C-SG 3 PORV CNTL
2-HIC-62-130C-VCT LEVEL CONTROL
2-HIC-62-93 C-CHARGING FLOW CNTL
2-HIC-63-65C-CL ACCUM N2 VENT
2-HIC-62-78C-LTDN HX OUTL TEMP
2-HTC-62-81C-LTDN PRESSURE CNTL
2-HIC-74-28C-RHR HX B OUTL CNTL
2-PIC-1-13C-SG 2 PORV CNTL
2-PIC-1-31C-SG 4 PORV CNTL
1-M-31 presently has the Condenser Vacuum Exhaust Monitor
RM-90-450 mounted. This monitor will be removed before
Unit 2 operation. Then both 1-M-3 land 2-M-31 will be blank.
DIFFERENCE
T
T
DURATION
SYSTEM
Various
INDICATIONS &
CONTROLS
Room Layout
configuration of
components on panel
2-L-11 A panel and
1-L-ll A panel.
Auxiliary Control
Room Layout
configuration of
components on panel
2-L-1 1 B panel and
1 -L- 1 1 B panel.
PANEL
ACR
DCN/
EDCR
52357
SYS
#
E2-63
This will not have an impact on operator actions as the controls
are manipulated via a checklist that is specific to each Unit.
The instruments on the panels are installed opposite hand in
respect to the I3ailey/GeMac panel in the room. On 1-L-11 B,
panel layout of components start with system 77 switches as
you enter the room and progresses to the system 1 components
mounted next to the GeMac panel. For 2-L-l 1 B, panel layout
starts with the system 1 switches as you enter the room and
O-XS-62-241 Boric Acid Tank C Recirculation flow is a
common loop and installed on 1-L-11A panel only. There will
be no matching transfer switch for Unit 2 located in this
location on 2-L-11A.
In Unit 1 the AFW Foxboro SPEC200 system is located in the
large 2-L-l 1A Panel. In Unit 2 the location of the equipment
will be in the smaller “Bailey Section” 2-L-1 1A Panel, which
is located next to the large 2L-1 1A Panel.
The location of LIC-3-l56B and LIC-3-164B on panel 2-LI 1A was not moved due to panel stiffeners as stated above.
sides of the panel stiffener than those on 1-L-1 1A. This
variation cannot be avoided due to the panel structure; however
there are no significant differences to the extent that the
operator would not be confused as to the component location
between units. This difference in the layout of components
will cause the panel stiffeners for panel 2-.L 11 A to interfere
with the relocation of some of the instruments mounted on the
panel. Because of this problem, XS-63-.llO will remain in its
original locations and will not move to match Panel l-L-HA.
These instruments on the panels are installed opposite hand in
respect to the Bailey/GeMac panel in the room.
DIFFERENCE
L
DURATION
.
BTrain2-HS-3945B
.
003
Feedwater
Manual Isolation
Control Capability
for the Main Feed
Water Regulating
Valves:
A Train 2-HS-3.
945A
54144
068
Reactor
Coolant
UNIT 2
RECORDER
2-XR-068-0003C
RCS Temperature
Trend
Ll0
SYS
#
52690
SYSTEM
INDICATIONS &
CONTROLS
PANEL
DCN/
EDCR
E2-64
The additional locally operated switch will not have an impact
on operator actions as its use is procedurally directed.
The manual isolation control capability for the Main Feed
Water Regulating Valves requires the installation of a second
hand switch for the B Trained solenoids Both the A train (2HS-3-945A) and B Train (2-HS3-945A) switch includes a
shorting contact across the solenoid coils to ensure the coil
does not energize due to an App R event. 2-FSV-335D, 48D,
90D and 103D solenoid valves are retained and wired by this
EDCR to support the function
This will change the way information is displayed to the
operator.
This will not have an impact on operator actions as the controls
are manipulated via a checklist that is specific to each Unit.
Unit 2 will have Paperless digital recorders. Unit 1 is replacing
these recorders as they fail.
In Unit 1 the AFW Foxboro SPEC200 system is located in the
large 2-L-11A Panel. In Unit 2 the location of the equipment
will be in the smaller “Bailey Section” 2-L-l IA Panel, which
is located next to the large 2L-l1A Panel.
progresses to the system 77 components mounted next to the
GeMac panel. This difference in the layout of components will
cause the panel stiffeners for panel 2-L- 1 1 B to interfere with
the relocation of the some of the instruments mounted on the
panel.
The locations of L1C-3-148B and L1C-3-171 B on panel 2-L1 1 B was not moved on panel 2-L-1 1 B due to panel stiffeners
as stated above.
DIFFERENCE
L
T
L
DURATION
SYS
#
001
001
001
SYSTEM
Steam
Generators
001
Main Steam
Westinghouse design
D3 Steam Generators
on Unit 2
Unit 2 installs new
HP and LP turbines.
Moisture Separator
Reheaters will be
replaced on Unit 2
54762
52866
53262
PANEL
INDICATIONS &
CONTROLS
DCN/
EDCR
E2-65
Unit 2 MSRs will be upgraded resulting in some flow
differences and improved instrumentation. The general
procedural direction for operations will be the same although
some setpoints may be different.
1) Mass flow rates to all Moisture Separator Reheater (MSR)
drain tanks increase because of improvements to the high
pressure turbine and the new MSRs.
2) Mass flow rates through the MSR operating vents decrease
because of improved MSR design. Mass flows from the MSR
low pressure operating vents will be directed to the low
pressure reheater drain header instead of the Number 2
extraction steam lines as on Unit 1.
3) System 1, System 5 and System 6 valves on the 755 foot
The general procedural direction for operations will be the
same although some setpoints may be different.
The Unit 2 S/G’s have one more step in the warm up process
governed by SOIs. The differences in steam generator design
result in slightly different response characteristics.
Unit 2 installs new HP Turbine (Rotor, Inner Cylinder, Blade
Rings) and LP Turbines (Rotors and Inner Casings).
The new turbines are designed to function in the same manner
as the set on Unit 1.
The volumes, recirculation ratios, tube heights & materials are
different and will result in slightly different transient
responses. The Unit 2 Steam Generators are the same design
that was originally installed in Unit 1.
Unit 1 replaced the Steam Generators with Westinghouse
design 68-AXP.
DIFFERENCE
L
L
L
DURATION
Unit 2 Generator
Protective Relaying
53734
Generator
Protective
Generator
Cooling
Unit 2 H2 Gas Dryer
will be different
SYSTEM
53479
INDICATIONS &
CONTROLS
Turbine Driven AFW Auxiliary
Pump Minimum
Feedwater
Speed is higher on
Unit 2
PANEL
53276
DCN/
EDCR
244
035
003
B
SYS
#
E2-66
The higher Unit 2 rpm will not result in system operation or
response differences.
Functionality of the Unit 1 Dryer and the Unit 2 Dryer is the
same. The Unit 1 Local Dryer controls are a hardwired switch,
relay, indicating light and timer configuration, and the Unit 2
Local Dryer is a PLC and Touch Screen Configuration.
This will not have an impact on operator actions.
Unit 2 Generator Protective Relaying will incorporate a one
out of two twice logic instead of the existing two out of two as
elevation of the Turbine Building will be located differently
from Unit I due to System 1, System 5 and System 6 piping
being re-routed to facilitate maintenance on the MSR reheater
bundles.
4) The Unit 2 MSRs will be supplied with fifty thermocouples
instead of seventy-six thermocouples as on the Unit 1 MSRs,
and the Unit 2 MSRs will be supplied with two junction boxes
per MSR instead of four as on Unit 1.
5) For Unit 2, all 300 thermocouples supplied with the six
MSRs will be utilized as opposed to the 138 thermocouples
utilized by Unit 1.
6) The Unit 2 Main Feedwater Pump Turbines are connected to
MSRs A-2 and B-2 as opposed to MSRs A-l and B-l on Unit
1 because of the original plant design.
The Unit 1 Turbine Driven Aux. Feedwater Pump (TDAFWP)
Turbine speed controller is set at 2076 rpm. In order to
accommodate current available pressure switches, mechanical
calculation HCGLCSO3 0983, Revision 006, increased the Unit
2 TDAFWP minimum speed setting for the Unit 2 TDAFWP
Turbine speed controller to 2260 rpm. The increase will ensure
that the Unit 2 TDAFWP does not inadvertently transfer its
steam supply to a faulted steam generator, as well as provides
additional stage runout protection.
DIFFERENCE
L
L
DURATION
068
Reactor
Unit 2 RCP
Aux
LEFM
Unit 2 uses the new
design Check Plus
LEFM System-
52310
52420
099
Process
Protection
Unit 2 has Eagle 21
loops with 4-2OmA
Transmitters
52319
SYS
#
006
Relaying
SYSTEM
Heater
Drains and
Vents
INDICATIONS &
CONTROLS
#3 & 7 Heater Drain
Tank Level Control
PANEL
53314
53323
52378
DCN/
EDCR
E2-67
Unit 2 is replacing the TEC RCP Vibration Monitoring System
This will not have an impact on operator actions.
Unit 2 will install the LEFM Check-Plus system (16
transducers on spool-piece). The LEFM installed on Unit 1 is
a Check system, which has 8 transducers.
Unit 2 Eagle 21 is functionally the same as Unit I
Eagle 21. Unit 2 current input loops will be 4-20 mA. Unit I
uses a combination of 4-20 mA and 10-50 mA current input
loops. Unit 2 will use 4-20 mA transmitters in Eagle 21. 4-20
mA transmitters are the industry standard, require less power
than the Unit 1 10-50 mA transmitters, and qualified 4-20 mA
transmitters are more widely available than the 10-50 mA
transmitters.
This changes the method in which the operator interfaces with
the control, information is displayed, and increases fault
tolerance. (Reference Section 2.2.4)
This will not have an impact on operator actions.
Unit 2 will have independent pump trips for HDT pumps vs.
Unit 1 simultaneous trip. Unit 2 will have Foxboro level
control hand stations, which develop the level signals from
redundant transmitters. Unit 2 scale and control range will be
different. Annunciation scheme will also be different.
used on Unit 1
DIFFERENCE
L
T
L
L
DURATION
53559
DCN/
EDCR
047
Turbine
Main Turbine and
Local
Electric
Room
B
SYS
Coolant
Pumps
SYSTEM
INDICATIONS &
CONTROLS
Vibration System
will be upgraded
PANEL
E2-68
This will change the way information is displayed to the
operator.
The Unit 2 Bentley Nevada 3500 series TSI system, while
Unit 2 RCP vibration monitors and display will be accessible
in cabinet 1-R-176, which is adjacent to 0-R-139, in the Unit 1
Auxiliary Instrumentation Room. Velocity signal cables from
JB 3242 are terminated at cabinet l-R-176 so there will be no
selector switches in JB 3242 for use with a portable diagnostic
monitor for the velocity probes on Unit 2. Signals from all
transducers are sent to the Bentley Nevada (B-N) 3500
monitors in cabinet 1 -R- 176 located in the Unit 1 Auxiliary
Instrument Room outside containment. Vibration amplitudes
may be read on a rack mounted LCD display located on the
cabinet, on the B-N computer, or via ICS. The system serves
an Annunciator function (MCR Annunciator 96-F) and
communicates with the B-N data manager computer and the
Integrated Computer System (ICS). All setpoints identified in
the procedure will remain unchanged for Unit 2. An additional
Annunciator alarm input will be added to the Unit 2 system to
alert the Operators if the motor casing vibration setpoint is
breached, whereas these points were checked manually using
procedure TI-3 1.02 at JB 3241 using a handheld meter on Unit
1.
with a BN 3500 monitoring system since the TEC system is
obsolete. Obsolete items are replaced with those equal in fit,
form and function. The Unit I RCP vibration monitors and
amplitude meters will be accessible in cabinet 0-R-l39 in the
Unit I Aux Inst Rim The multipoint selector switches to read
the velocity probe using a portable diagnostic monitor are
located in JB 3241 near column A5-W at El 73T in the
Penetration Room.
DIFFERENCE
L
DURATION
035
Main
Generator
New Generator Core
Condition Monitor
panel will replace
drop alarm boxes and
hydrogen purity
meter.
53246
53479
SYS
#
E
003
002
Supervisory
Vibration
Main
Feedwater
SYSTEM
Condensate
INDICATIONS &
CONTROLS
Feed Pump Vibration
Local TSI panel and
indications
2-FCV-002-0035A
Condensate Hotwell
Discharge Flow will
be controlled from 3
transmitters.
TSI
panel
only
PANEL
54928
DCN/
EDCR
E2-69
Unit 2 will exhibit increased fault tolerance with reduced
operator actions.
Control Room operator actions are the same from the
annunciator response procedure.
This will change the way information is displayed to the
operator.
2-FCV-002-0035A is controlled by signals from three FTs; 2FT-002-0035A, 2-FT-002-00358, and 2-FT-002-00350. The
input signal processing and control output to the valve were
modified by EDCR 52378. Unit 1 is controlled by the signal
from a single FT. The redundancy is to remove a single point
of failure in the system.
Unit 2 FW Pumps will have coincidence logic added to the
high thrust trip. Unit 2 having the coincidence logic will not
change operator actions.
functionally identical to Unit 1 in regard to the points
monitored and the indications displayed in the control room,
represents a change in technology from the obsolete 3300
Series instrumentation used in Unit 1. The control room
indications are not impacted.
DIFFERENCE
L
L
L
DURATION
ATTACHMENT 2 -Technical Specifications Differences
a. IS Definitions Section 1.1
i.
Power Level Definition: Unit 1 3459 MWt, Unit 2 341 1 MWt Unit 1 TS
approved Power Uprate using Leading Edge Flow Meter (LEFM)
ii.
Added Power Distribution Monitoring System (PDMS)
that replaces movable incore detectors.
—
new fixed incore system
b. TS 3.1.8 and Surveillance Requirements (SRs) 3.2.1.2, 3.3.1.3, and 3.3.1.6—changed
reference to movable incore detectors to PDMS.
c.’ TS Table 3.3.1-1 and 3.3.2-1 added footnotes in accordance with TSTF-493 that
directs how to reset setpoint values during surveillance. No setpoints were changed.
—
d. TS Table 3.3.3-1 footnotes F and H reflect new Common
system. Unit 1 references the ICCM system.
Q post-accident monitoring
e. SR 3.3.2.5 and 3.3.6.5 added allowance for use of Potter Brumfield MDR series
relays. Unit 1 references Westinghouse relays only.
—
f* TS 3.4.7. 3/4/10 and 3.4.12 Unit 1 references a temperature of 350°F. Unit 2 uses
Cold Overpressure Mitigation System (COMS) arming.
—
g. SR 3.5.1.4 and 3.5.4.3 Unit 1 includes “Notes” discussing TPBARs. Unit 2 does not
have TPBARs. All other requirements in the Technical Specification and surveillance
are identical.
—
h. TS Table 3.7.1-1 Allowable rated thermal power for Main Steam Safety Valves:
# of Operable MSSV
Unit 1 Rated Thermal Power
Unit 2 Rated Thermal Power
3
4l%
42%
2
25%
26%
TRM Differences:
a. TRM Definitions: Rated Thermal Power, Unit 1 3459 MWt, Unit 2 3411 MWt Unit
1 TS approved Power Uprate using Leading Edge Flow Meter (LEFM)
E2-70
b. TRM 3.3.3: Unit 1 has movable incore detectors. Unit 2 used fixed incore detectors
referred to as Power Distribution Monitoring System (PDMS)
a. TRM 3.3.7: Unit 1 has a technical requirement in support of leading edge flow
meters (LEFMs). Unit 2 will not implement LEFM associated power uprate until NRC
licensing review and approval of the LEFM uprate is completed.
b.
*=
These sections will be changed in Unit 1 Technical Specifications to match Unit 2.
Upon completion of the Unit 1 changes these differences will be eliminated.
E2-71
ATTACHMENT 3- NRC Guidance
NUREG-1021, ES-204, C.1.c, PROCESSING WAIVERS REQUESTED BY
REACTOR OPERATOR AND SENIOR REACTOR OPERATOR
APPLICANTS:
Facility licensees having units designed by the same nuclear steam supply system
vendor and operated at approximately the same power level may request dual
licensing for their operators. Similarly, if the units of a multi-unit facility are
nearly identical, the facility licensee may request
a waiver of the examination requirements for the second and subsequent units.
In either case, the facility licensee must justify to the NRC that the differences
between the units are not so significant that they could affect the operator’s ability
to operate each unit safely and competently. Further, the facility licensee must
submit for NRC review the details of the training and certification program. The
analysis and summary of the differences on which the applicants must be trained
will include the following, as applicable:
• facility design and systems relevant to control room personnel
• technical specifications
• procedures (primarily abnormal and emergency operating)
• control room design and instrument location
• operational characteristics
• administrative procedures related to conduct of operations at a multi-unit
site (e.g., shift manning and response to accidents and fires)
• the expected method of rotating personnel between units and the re
familiarization training to be conducted before an operator assumes
responsibility on a new unit
7.2 Regulatory Guide 1.149, C.2, USE OF A SIMULATOR FOR MULTIPLE
PLANTS
If a licensee wishes to use a simulation facility to train or examine operators for more
than one nuclear power plant, it must be able to demonstrate to the NRC that the
differences between the plants are not so significant that they will result in negative
training. This demonstration should include an analysis and summary of the differences
between each plant, including:
1. Facility design and systems relevant to control room personnel,
2. Technical specifications,
3. Procedures, primarily abnormal and emergency operating procedures,
4. Control room design and instrument/control location, and
5. Operational characteristics.
7.3 1 OCFR55.46 Simulation facilities.
E2-72
(a) General. This section addresses the use of a simulation facility for the administration
of the operating test and plant-referenced simulators to meet experience requirements for
applicants for operator and senior operator licenses.
(b) Commission-approved simulation facilities and Commission approval of use ofthe
plant in the administration ofthe operating test.
(1) Facility licensees that propose to use a simulation facility, other than a plantreferenced simulator, or the plant in the administration of the operating test under
§ 55.45(b)(1) or 55.45(b)(3), shall request approval from the Commission. This
request must include:
(i) A description of the components of the simulation facility intended to be used, or the
way the plant would be used for each part of the operating test, unless previously
approved; and
(ii) A description of the performance tests for the simulation facility as part of the
request, and the results of these tests; and (iii) A description of the procedures for
maintaining examination and test integrity consistent with the requirements of § 55.49.
(2) The Commission will approve a simulation facility or use of the plant for
administration of operating tests if it finds that the simulation facility and its proposed
use, or the proposed use of the plant, are suitable for the conduct of operating tests for the
facility licensee’s reference plant under § 55.45(a).
(c) Plant-referenced simulators.
(1) A plant-referenced simulator used for the administration of the operating test or to
meet experience requirements in § 55.3 1(a)(5) must demonstrate expected plant response
to operator input and to normal, transient, and accident conditions to which the simulator
has been designed to respond. The plant-referenced simulator must be designed and
implemented so that it:
(i) Is sufficient in scope and fidelity to allow conduct of the evolutions listed in §sS
55.45(a)(1) through (13), and 55.59(c)(3)(i)(A) through (AA), as applicable to the design
of the reference plant.
(ii) Allows for the completion of control manipulations for operator license applicants.
(2) Facility licensees that propose to use a plant-referenced simulator to meet the control
manipulation requirements in § 55.31 (a)(5) must ensure that:
(i) The plant-referenced simulator utilizes models relating to nuclear and thermalhydraulic characteristics that replicate the most recent core load in the nuclear power
reference plant for which a license is being sought; and
(ii) Simulator fidelity has been demonstrated so that significant control manipulations are
completed without procedural exceptions, simulator performance exceptions, or deviation
from the approved training scenario sequence.
(3) A simulation facility consisting solely of a plant-referenced simulator must meet the
requirements of paragraph (c)( 1) of this section and the criteria in paragraphs (d)( 1) and
(4) of this section for the Conunission to accept the plant-referenced simulator for
conducting operating tests as described in § 5 5.45(a) of this part, requalification training
as described in § 55.59(c)(3) of this part, or for performing control manipulations that
affect reactivity to establish eligibility for an operator’s license as described in §
55.31 (a)(5).
E2-73
ATTACHMENT 4- Acronyms
AlE
AEH
AMSAC
AOl
ATWS
AUO
BEACON
BOP
CAP
CATD
COMS
DCS
DCN
DSEP
EDCR
EOI
EP
FSAR
GO
GPM
HFE
I/A
ICCM
ICS
ILT
JFG
JPM
LEFM
LOR
MCR
MFPIMFPT
MFW
MCR
NCO
NIS
NSSS
OJT
OL
PAMS
PASS
PDMS
PER
PORV
PPM
RO
RVLIS
SM
SOT
Architecture Engineer
Analog Electro-Hydraulic
(ATWS) Mitigating System Actuating Circuitry
Abnormal Operating Instructions
Anticipated Transient Without SCRAM
Non-Licensed Operator
Best Estimate Analysis of Core Operations
Balance of Plant
Corrective Action Program
Category Drawing (usually Cat I, Cat II, etc)
Cold Overpressure Mitigation System
Digital Control System
Design Change Notice
Detailed Scoping Estimating and Planning
Engineering Design Control Request
Emergency Operating Instructions
Emergency Preparedness
Final Safety’ Analysis Report
General Operating Procedures
Gallons per Minute
Human Factors Engineering
Intelligent Automation
Inadequate Core Cooling Monitoring System
Integrated Computer System
Initial License Training
Job Familiarization Guide
Job Performance Measure
Leading Edge Flow Meter
Licensed Operator Requalification Training
Main Control Room
Main Feedwater Pump / Main Feedwater Pump Turbine
Main Feedwater
Main Control Room
Nuclear Central Office Tracking Items
Nuclear Instrumentation System
Nuclear Steam Supply System
On-the-Job Training
Operating License
Post Accident Monitoring System
Post Accident Sampling System
Power Distribution Monitoring System
Problem Evaluation Report
Power Operated Relief Valve
Parts per Million
Reactor Operator
Reactor Vessel Level Indication System
Shift Manager
Standard Operating Instructions
E2-74
SP
SQN
SR
SRO
STA
TNA
TPBARs
TPE
TRM
TSM
TVA
UPS
WBN
WJNC ISE
Special Programs
Sequoyah Nuclear Plant
Surveillance Requirements, also Service Report
Senior Reactor Operator
Shift Technical Advisor
Training Needs Analysis
Tritium Producing Burnable Absorber Rods
Training Performance Evaluation
Technical Requirements Manual
Technical Specification Monitor
Tennessee Valley Authority
Uninterruptible Power Supply
Watts Bar Nuclear Plant
Westinghouse In-Core Information Surveillance & Engineering
E2-75
ATTACHMENT 5— Unit Comparison Control Room Photos
UNIT 1
M-1 Auxiliary Power
I
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M-1 Auxiliary Power
II
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E2-76
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—
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E2-85
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E2-86
E2-87
L2-88
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UNIT 1 M-15 Water Service
E2-89
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E2-90
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E2-91
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E2-93
FIGURE 2— Control Room Layout