Biweekly Notice; Applications and Amendments to Facility Operating Licenses Involving No Significant Hazards Considerations, 40742-40759 [06-6246]
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40742
Federal Register / Vol. 71, No. 137 / Tuesday, July 18, 2006 / Notices
request for a hearing or petition for
leave to intervene was filed following
this notice.
The Commission has prepared an
Environmental Assessment related to
the action and has determined not to
prepare an environmental impact
statement. Based upon the
environmental assessment, the
Commission has concluded that the
issuance of the amendment will not
have a significant effect on the quality
of the human environment (71 FR
37614).
For further details with respect to the
action, see (1) the application for
amendment dated July 7, 2005, as
supplemented by letters dated August
15, September 30, and December 6, 9,
and 22, 2005, and January 11 and 25,
February 16, March 3 and 24, and May
9 and 19, 2006, (2) Amendment No. 97
to License No. DPR–18, (3) the
Commission’s related Safety Evaluation,
and (4) the Commission’s
Environmental Assessment. Documents
may be examined, and/or copied for a
fee, at the NRC’s Public Document
Room, located at One White Flint North,
Public File Area O1 F21,11555
Rockville Pike (first floor), Rockville,
Maryland. Publicly available records
will be accessible electronically from
the Agencywide Documents Access and
Management Systems (ADAMS) Public
Electronic Reading Room on the Internet
at the NRC Web site, https://
www.nrc.gov/reading-rm/adams.html.
Persons who do not have access to
ADAMS or who encounter problems in
accessing the documents located in
ADAMS should contact the NRC Public
Document Room Reference staff by
telephone at 1–800–397–4209, or 301–
415–4737, or by e-mail to pdr@nrc.gov.
Dated at Rockville, Maryland, this 11th day
of July 2006.
For the Nuclear Regulatory Commission.
Patrick D. Milano,
Senior Project Manager,Plant Licensing
Branch I–1, Division of Operating Reactor
Licensing,Office of Nuclear Reactor
Regulation.
[FR Doc. E6–11320 Filed 7–17–06; 8:45 am]
Week of July 24, 2006—Tentative
Wednesday, July 26, 2006
1:50 p.m. Affirmation Session (Public
Meeting) (Tentative).
a. Pa’ina Hawaii, LLC, unpublished
April 27, 2006 Memorandum and
Order (accepting the intervenor’s
and NRC Staff’s Joint Stipulation
regarding two admitted
environmental contentions)
(Tentative).
b. David Geisen, LBP–06–13 (May 19,
2006) (Tentative).
c. Exelon Generation Company, LLC
(Early Site Permit for Clinton ESP),
System Energy Resources, Inc.
(Early Site Permit for Grand Gulf
ESP) (Tentative).
d. Florida Power & Light Co., et al.,
Docket Nos. 50–250–LT, et al.,
International Brotherhood of
Electrical Workers’ ‘‘Petition to File
Motion to Intervene and Protest
Out-of-Time’’ and ‘‘Motion for
Hearing and Right to Intervene and
Protest’’ (Tentative).
Thursday, July 27, 2006
9:30 a.m. Briefing on Office of
International Programs (OIP)
Programs, Performance, and Plans
(Public Meeting) (Contact: Karen
Henderson, 301–415–0202).
This meeting will be webcast live at
the Web address—https://www.nrc.gov.
1:30 p.m. Briefing on Equal
Employment Opportunity (EEO)
Programs. (Public Meeting)
(Contact: Barbara Williams, 301–
415–7388).
This meeting will be webcast live at
the Web address—https://www.nrc.gov.
Week of July 31, 2006—Tentative
There are no meetings scheduled for
the Week of July 31, 2006.
Week of August 7, 2006—Tentative
There are no meetings scheduled for
the Week of August 14, 2006.
Sunshine Act; Notice of Meeting
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There are no meetings scheduled for
the Week of July 17, 2006.
Week of August 14, 2006—Tentative
NUCLEAR REGULATORY
COMMISSION
Week of August 21, 2006—Tentative
Weeks of July 17, 24, 31, August
7, 14, 21, 2006.
PLACE: Commissioners’ Conference
Room, 11555 Rockville Pike, Rockville,
Maryland.
STATUS: Public and closed.
DATES:
16:25 Jul 17, 2006
Week of July 17, 2006
There are no meetings scheduled for
the Week of August 7, 2006.
BILLING CODE 7590–01–P
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There are no meetings scheduled for
the Week of August 21, 2006.
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The schedule for Commission
meetings is subject to change on short
notice. To verify the status of meetings
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call (recording)—(301) 415–1292.
Contact person for more information:
Michelle Schroll, (301) 415–1662.
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The NRC Commission Meeting
Schedule can be found on the Internet
at: https://www.nrc.gov/what-we-do/
policy-making/schedule.html.
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The NRC provides reasonable
accommodation to individuals with
disabilities where appropriate. If you
need a reasonable accommodation to
participate in these public meetings, or
need this meeting notice or the
transcript or other information from the
public meetings in another format (e.g.
braille, large print), please notify the
NRC’s Disability Program Coordinator,
Deborah Chan, at 301–415–7041, TDD:
301–415–2100, or by e-mail at
DLC@nrc.gov. Determinations on
requests for reasonable accommodation
will be made on a case-by-case basis.
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This notice is distributed by mail to
several hundred subscribers; if you no
longer wish to receive it, or would like
to be added to the distribution, please
contact the Office of the Secretary,
Washington, DC 20555 (301–415–1969).
In addition, distribution of this meeting
notice over the Internet system is
available. If you are interested in
receiving this Commission meeting
schedule electronically, please send an
electronic message to dkw@nrc.gov.
Dated: July 13, 2006.
R. Michelle Schroll,
Office of the Secretary.
[FR Doc. 06–6302 Filed 7–14–06; 9:59 am]
BILLING CODE 7590–01–M
NUCLEAR REGULATORY
COMMISSION
Biweekly Notice; Applications and
Amendments to Facility Operating
Licenses Involving No Significant
Hazards Considerations
I. Background
Pursuant to section 189a.(2) of the
Atomic Energy Act of 1954, as amended
(the Act), the U.S. Nuclear Regulatory
Commission (the Commission or NRC
staff) is publishing this regular biweekly
notice. The Act requires the
Commission publish notice of any
amendments issued, or proposed to be
issued and grants the Commission the
authority to issue and make
immediately effective any amendment
to an operating license upon a
determination by the Commission that
such amendment involves no significant
hazards consideration, notwithstanding
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the pendency before the Commission of
a request for a hearing from any person.
This biweekly notice includes all
notices of amendments issued, or
proposed to be issued from June 23,
2006 to July 6, 2006. The last biweekly
notice was published on July 5, 2006 (71
FR 38180).
Notice of Consideration of Issuance of
Amendments to Facility Operating
Licenses, Proposed No Significant
Hazards Consideration Determination,
and Opportunity for a Hearing
The Commission has made a
proposed determination that the
following amendment requests involve
no significant hazards consideration.
Under the Commission’s regulations in
10 CFR 50.92, this means that operation
of the facility in accordance with the
proposed amendment would not (1)
involve a significant increase in the
probability or consequences of an
accident previously evaluated; or (2)
create the possibility of a new or
different kind of accident from any
accident previously evaluated; or (3)
involve a significant reduction in a
margin of safety. The basis for this
proposed determination for each
amendment request is shown below.
The Commission is seeking public
comments on this proposed
determination. Any comments received
within 30 days after the date of
publication of this notice will be
considered in making any final
determination. Within 60 days after the
date of publication of this notice, the
licensee may file a request for a hearing
with respect to issuance of the
amendment to the subject facility
operating license and any person whose
interest may be affected by this
proceeding and who wishes to
participate as a party in the proceeding
must file a written request for a hearing
and a petition for leave to intervene.
Normally, the Commission will not
issue the amendment until the
expiration of 60 days after the date of
publication of this notice. The
Commission may issue the license
amendment before expiration of the 60day period provided that its final
determination is that the amendment
involves no significant hazards
consideration. In addition, the
Commission may issue the amendment
prior to the expiration of the 30-day
comment period should circumstances
change during the 30-day comment
period such that failure to act in a
timely way would result, for example in
derating or shutdown of the facility.
Should the Commission take action
prior to the expiration of either the
comment period or the notice period, it
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will publish in the Federal Register a
notice of issuance. Should the
Commission make a final No Significant
Hazards Consideration Determination,
any hearing will take place after
issuance. The Commission expects that
the need to take this action will occur
very infrequently.
Written comments may be submitted
by mail to the Chief, Rules and
Directives Branch, Division of
Administrative Services, Office of
Administration, U.S. Nuclear Regulatory
Commission, Washington, DC 20555–
0001, and should cite the publication
date and page number of this Federal
Register notice. Written comments may
also be delivered to Room 6D22, Two
White Flint North, 11545 Rockville
Pike, Rockville, Maryland, from 7:30
a.m. to 4:15 p.m. Federal workdays.
Copies of written comments received
may be examined at the Commission’s
Public Document Room (PDR), located
at One White Flint North, Public File
Area O1F21, 11555 Rockville Pike (first
floor), Rockville, Maryland. The filing of
requests for a hearing and petitions for
leave to intervene is discussed below.
Within 60 days after the date of
publication of this notice, the licensee
may file a request for a hearing with
respect to issuance of the amendment to
the subject facility operating license and
any person whose interest may be
affected by this proceeding and who
wishes to participate as a party in the
proceeding must file a written request
for a hearing and a petition for leave to
intervene. Requests for a hearing and a
petition for leave to intervene shall be
filed in accordance with the
Commission’s ‘‘Rules of Practice for
Domestic Licensing Proceedings’’ in 10
CFR part 2. Interested persons should
consult a current copy of 10 CFR 2.309,
which is available at the Commission’s
PDR, located at One White Flint North,
Public File Area 01F21, 11555 Rockville
Pike (first floor), Rockville, Maryland.
Publicly available records will be
accessible from the Agencywide
Documents Access and Management
System’s (ADAMS) Public Electronic
Reading Room on the Internet at the
NRC Web site, https://www.nrc.gov/
reading-rm/doc-collections/cfr/. If a
request for a hearing or petition for
leave to intervene is filed within 60
days, the Commission or a presiding
officer designated by the Commission or
by the Chief Administrative Judge of the
Atomic Safety and Licensing Board
Panel, will rule on the request and/or
petition; and the Secretary or the Chief
Administrative Judge of the Atomic
Safety and Licensing Board will issue a
notice of a hearing or an appropriate
order.
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As required by 10 CFR 2.309, a
petition for leave to intervene shall set
forth with particularity the interest of
the petitioner in the proceeding, and
how that interest may be affected by the
results of the proceeding. The petition
should specifically explain the reasons
why intervention should be permitted
with particular reference to the
following general requirements: (1) The
name, address, and telephone number of
the requestor or petitioner; (2) the
nature of the requestor’s/petitioner’s
right under the Act to be made a party
to the proceeding; (3) the nature and
extent of the requestor’s/petitioner’s
property, financial, or other interest in
the proceeding; and (4) the possible
effect of any decision or order which
may be entered in the proceeding on the
requestor’s/petitioner’s interest. The
petition must also set forth the specific
contentions which the petitioner/
requestor seeks to have litigated at the
proceeding.
Each contention must consist of a
specific statement of the issue of law or
fact to be raised or controverted. In
addition, the petitioner/requestor shall
provide a brief explanation of the bases
for the contention and a concise
statement of the alleged facts or expert
opinion which support the contention
and on which the petitioner/requestor
intends to rely in proving the contention
at the hearing. The petitioner/requestor
must also provide references to those
specific sources and documents of
which the petitioner is aware and on
which the petitioner/requestor intends
to rely to establish those facts or expert
opinion. The petition must include
sufficient information to show that a
genuine dispute exists with the
applicant on a material issue of law or
fact. Contentions shall be limited to
matters within the scope of the
amendment under consideration. The
contention must be one which, if
proven, would entitle the petitioner/
requestor to relief. A petitioner/
requestor who fails to satisfy these
requirements with respect to at least one
contention will not be permitted to
participate as a party.
Those permitted to intervene become
parties to the proceeding, subject to any
limitations in the order granting leave to
intervene, and have the opportunity to
participate fully in the conduct of the
hearing.
If a hearing is requested, and the
Commission has not made a final
determination on the issue of no
significant hazards consideration, the
Commission will make a final
determination on the issue of no
significant hazards consideration. The
final determination will serve to decide
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when the hearing is held. If the final
determination is that the amendment
request involves no significant hazards
consideration, the Commission may
issue the amendment and make it
immediately effective, notwithstanding
the request for a hearing. Any hearing
held would take place after issuance of
the amendment. If the final
determination is that the amendment
request involves a significant hazards
consideration, any hearing held would
take place before the issuance of any
amendment.
A request for a hearing or a petition
for leave to intervene must be filed by:
(1) First class mail addressed to the
Office of the Secretary of the
Commission, U.S. Nuclear Regulatory
Commission, Washington, DC 20555–
0001, Attention: Rulemaking and
Adjudications Staff; (2) courier, express
mail, and expedited delivery services:
Office of the Secretary, Sixteenth Floor,
One White Flint North, 11555 Rockville
Pike, Rockville, Maryland 20852,
Attention: Rulemaking and
Adjudications Staff; (3) E-mail
addressed to the Office of the Secretary,
U.S. Nuclear Regulatory Commission,
HearingDocket@nrc.gov; or (4) facsimile
transmission addressed to the Office of
the Secretary, U.S. Nuclear Regulatory
Commission, Washington, DC,
Attention: Rulemakings and
Adjudications Staff at (301) 415–1101,
verification number is (301) 415–1966.
A copy of the request for hearing and
petition for leave to intervene should
also be sent to the Office of the General
Counsel, U.S. Nuclear Regulatory
Commission, Washington, DC 20555–
0001, and it is requested that copies be
transmitted either by means of facsimile
transmission to (301) 415–3725 or by email to OGCMailCenter@nrc.gov. A copy
of the request for hearing and petition
for leave to intervene should also be
sent to the attorney for the licensee.
Nontimely requests and/or petitions
and contentions will not be entertained
absent a determination by the
Commission or the presiding officer of
the Atomic Safety and Licensing Board
that the petition, request and/or the
contentions should be granted based on
a balancing of the factors specified in 10
CFR 2.309(a)(1)(i)–(viii).
For further details with respect to this
action, see the application for
amendment which is available for
public inspection at the Commission’s
PDR, located at One White Flint North,
Public File Area 01F21, 11555 Rockville
Pike (first floor), Rockville, Maryland.
Publicly available records will be
accessible from the ADAMS Public
Electronic Reading Room on the Internet
at the NRC Web site, https://
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www.nrc.gov/reading-rm/adams.html. If
you do not have access to ADAMS or if
there are problems in accessing the
documents located in ADAMS, contact
the PDR Reference staff at 1 (800) 397–
4209, (301) 415–4737 or by e-mail to
pdr@nrc.gov.
AmerGen Energy Company, LLC, Docket
No. 50–289, Three Mile Island Nuclear
Station, Unit 1 (TMI–1), Dauphin
County, Pennsylvania
Date of amendment request: May 15,
2006.
Description of amendment request:
The amendment would revise the
Technical Specification (TS)
requirements related to steam generator
tube integrity. The proposed changes are
generally consistent with Revision 4 to
Technical Specification Task Force
(TSTF) Standard Technical
Specification Change Traveler, TSTF–
449, ‘‘Steam Generator Tube Integrity.’’
The availability of this TS improvement
was announced in the Federal Register,
on May 6, 2005 (70 FR 24126) as part
of the consolidated line item
improvement process (CLIIP). The
proposed amendment includes changes
to licensing pages to delete License
Condition 2.c.(8), ‘‘Repaired Steam
Generators;’’ changes to TS 3.1.6,
‘‘LEAKAGE;’’ changes to TS Section
3.1.1.2, ‘‘Steam Generators and Steam
Generator (SG) Tube Integrity;’’ revising
TS Section 4.19, ‘‘Steam Generator (SG)
Tube Integrity;’’ adding new TS 6.9.6,
‘‘Steam Generator Tube Inspection
Report;’’ and adding new TS 6.19,
‘‘Steam Generator (SG) Program.’’
Basis for proposed no significant
hazards consideration determination
(NSHC): The NRC staff published a
notice of opportunity for comment in
the Federal Register on March 2, 2005
(70 FR 10298), on possible amendments
adopting TSTF–449, including a model
safety evaluation and model NSHC
determination, using the CLIIP. The
NRC staff subsequently issued a notice
of availability of the models for
referencing in license amendment
applications in the Federal Register on
May 6, 2005 (70 FR 24126). The licensee
affirmed the applicability of the
following NSHC determination in its
application dated May 15, 2006. As
required by 10 CFR 50.91(a), an analysis
of the issue of no significant hazards
consideration is presented below:
Criterion 1—The Proposed Change Does
Not Involve a Significant Increase in the
Probability or Consequences of an Accident
Previously Evaluated.
The proposed change requires a SG
Program that includes performance criteria
that will provide reasonable assurance that
the SG tubing will retain integrity over the
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full range of operating conditions (including
startup, operation in the power range, hot
standby, cooldown and all anticipated
transients included in the design
specification). The SG performance criteria
are based on tube structural integrity,
accident induced leakage, and operational
LEAKAGE.
A Steam Generator Tube Rupture (SGTR)
event is one of the design-basis accidents that
are analyzed as part of a plant’s licensing
basis. In the analysis of a SGTR event, a
bounding primary to secondary LEAKAGE
rate equal to the operational LEAKAGE rate
limits in the licensing basis plus the
LEAKAGE rate associated with a doubleended rupture of a single tube is assumed.
For other design-basis accidents such as
Main Steam Line Break (MSLB), rod ejection,
and reactor coolant pump locked rotor the
tubes are assumed to retain their structural
integrity (i.e., they are assumed not to
rupture). These analyses typically assume
that primary to secondary LEAKAGE for all
SGs is 1 gallon per minute or increases to 1
gallon per minute as a result of accidentinduced stresses. The accident-induced
leakage criterion introduced by the proposed
changes accounts for tubes that may leak
during design-basis accidents. The accidentinduced leakage criterion limits this leakage
to no more than the value assumed in the
accident analysis.
The SG performance criteria proposed
change to the TSs identifies the standards
against which tube integrity is to be
measured. Meeting the performance criteria
provides reasonable assurance that the SG
tubing will remain capable of fulfilling its
specific safety function of maintaining
reactor coolant pressure boundary integrity
throughout each operating cycle and in the
unlikely event of a design-basis accident. The
performance criteria are only a part of the SG
Program required by the proposed change to
the TSs. The program, defined by NEI
[Nuclear Energy Institute] 97–06, ‘‘Steam
Generator Program Guidelines,’’ includes a
framework that incorporates a balance of
prevention, inspection, evaluation, repair,
and leakage monitoring. The proposed
changes do not, therefore, significantly
increase the probability of an accident
previously evaluated.
The consequences of design-basis
accidents are, in part, functions of the DOSE
EQUIVALENT I–131 in the primary coolant
and the primary to secondary LEAKAGE
rates resulting from an accident. Therefore,
limits are included in the plant technical
specifications for operational leakage and for
DOSE EQUIVALENT I–131 in primary
coolant to ensure the plant is operated within
its analyzed condition. The typical analysis
of the limiting design-basis accident assumes
that the primary-to-secondary leak rate after
the accident is 1 gallon per minute with no
more than 500 gallons per day in any one SG,
and that the reactor coolant activity levels of
DOSE EQUIVALENT I–131 are at the TS
values before the accident.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary coolant chemistry controls. The
proposed approach updates the current TSs
and enhances the requirements for SG
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inspections. The proposed change does not
adversely impact any other previouslyevaluated design-basis accident and is an
improvement over the current TSs.
Therefore, the proposed change does not
affect the consequences of a SGTR accident
and the probability of such an accident is
reduced. In addition, the proposed change
does not affect the consequences of an MSLB,
rod ejection, or a reactor coolant pump
locked rotor event, or other previouslyevaluated accident.
Criterion 2—The Proposed Change Does
Not Create the Possibility of a New or
Different Kind of Accident From Any
Previously Evaluated.
The proposed performance-based
requirements are an improvement over the
requirements imposed by the current
technical specifications. Implementation of
the proposed SG Program will not introduce
any adverse changes to the plant design-basis
or postulated accidents resulting from
potential tube degradation. The result of the
implementation of the SG Program will be an
enhancement of SG tube performance.
Primary to secondary LEAKAGE that may be
experienced during all plant conditions will
be monitored to ensure it remains within
current accident analysis assumptions.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary or secondary coolant chemistry
controls. In addition, the proposed change
does not impact any other plant system or
component. The change enhances SG
inspection requirements.
Therefore, the proposed change does not
create the possibility of a new or different
type of accident from any accident
previously evaluated.
Criterion 3—The Proposed Change Does
Not Involve a Significant Reduction in the
Margin of Safety.
The SG tubes in pressurized-water reactors
are an integral part of the reactor coolant
pressure boundary and, as such, are relied
upon to maintain the primary system’s
pressure and inventory. As part of the reactor
coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as
a heat transfer surface between the primary
and secondary systems such that residual
heat can be removed from the primary
system. In addition, the SG tubes isolate the
radioactive fission products in the primary
coolant from the secondary system. In
summary, the safety function of an SG is
maintained by ensuring the integrity of its
tubes.
Steam generator tube integrity is a function
of the design, environment, and the physical
condition of the tube. The proposed change
does not affect tube design or operating
environment. The proposed change is
expected to result in an improvement in the
tube integrity by implementing the SG
Program to manage SG tube inspection,
assessment, repair, and plugging. The
requirements established by the SG Program
are consistent with those in the applicable
design codes and standards and are an
improvement over the requirements in the
current TSs.
For the above reasons, the margin of safety
is not changed and overall plant safety will
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be enhanced by the proposed change to the
TSs.
The NRC staff proposes to determine
that the amendment request involves no
significant hazards consideration.
Attorney for licensee: Mr. Brad
Fewell, Assistant General Counsel,
Exelon Generation Company, LLC, 200
Exelon Way, Kennett Square, PA 19348.
NRC Branch Chief: Darrell J. Roberts.
Duke Power Company LLC, Docket Nos.
50–269, 50–270, and 50–287, Oconee
Nuclear Station, Units 1, 2, and 3,
Oconee County, South Carolina
Date of amendment request: June 1,
2006.
Description of amendment request:
The proposed amendments would
revise the Updated Final Safety
Analysis Report (UFSAR) to incorporate
the use of a fiber-reinforced polymer
(FRP) system to strengthen existing
masonry walls against tornado effects.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Involve a significant increase in the
probability or consequences of an accident
previously evaluated.
Response: Physical protection from a
tornado event is a design basis criterion
rather than a requirement of a previously
analyzed UFSAR accident analysis.
The current licensing basis (CLB) for
Oconee states that systems, structures, and
components (SSC’s) required to shut down
and maintain the units in a shutdown
condition will not fail as a result of damage
caused by natural phenomena.
The in-fill masonry walls to be
strengthened using an FRP system are
passive, non-structural elements. The use of
an FRP system on existing Auxiliary Building
masonry walls will allow them to resist
uniform pressure loads resulting from a
tornado and will not adversely affect the
structure’s ability to withstand other design
basis events such as earthquakes or fires.
Therefore, the proposed use of FRP on
existing masonry walls will not significantly
increase the probability or consequences of
an accident previously evaluated.
2. Create the possibility of a new or
different kind of accident from any accident
previously evaluated.
Response: The final state of the FRP system
is passive in nature and will not initiate or
cause an accident. More generally, this
understanding supports the conclusion that
the potential for new or different kinds of
accidents is not created.
3. Involve a significant reduction in a
margin of safety.
Response: The application of an FRP
system to existing auxiliary building masonry
walls will either act to restore the margin of
safety described in the UFSAR, e.g., the Unit
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3 Control Room north wall, or enhance the
margin of safety, e.g., the West Penetration
Room walls, by increasing the walls’ ability
to resist tornado-induced differential
pressure and/or tornado wind. Consequently,
this change does not involve a significant
reduction in a margin of safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: Ms. Lisa F.
Vaughn, Legal Department (PB05E),
Duke Energy Corporation, 422 South
Church Street, Charlotte, North Carolina
28201–1006.
NRC Branch Chief: Evangelos C.
Marinos.
Energy Northwest, Docket No. 50–397,
Columbia Generating Station, Benton
County, Washington
Date of amendment request: May 22,
2006.
Description of amendment request:
The proposed license amendment
request would revise: (1) Surveillance
Requirement (SR) 3.8.1.11 to remove the
MODE restriction from Note 2 for Diesel
Generator (DG)–3 only, (2) SR 3.8.1.12
to remove the MODE restriction from
Note 2 for DG–3 only, (3) SR 3.8.1.16 to
remove the MODE restriction from the
Note for DG–3 only, and (4) Revise SR
3.8.1.19 to remove the MODE restriction
from Note 2 for DG–3 only.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Does the operation of Columbia
Generating Station in accordance with the
proposed amendment involve a significant
increase in the probability or consequences
of an accident previously evaluated?
Response: No.
The DG and its associated emergency loads
are accident mitigating features, not accident
initiating equipment. Therefore, there will be
no impact on any accident probabilities by
the approval of the requested amendment.
The design of plant equipment is not being
modified by these proposed changes. The
capability of DG–1 and DG–2 to supply
power to their safety related buses as
designed will not be compromised by
permitting performance of DG–3 testing
during power operations. Columbia’s
Technical Specifications require the RCIC
[reactor core isolation cooling] system to be
operable whenever this testing is performed
at power. This ensures that the high-pressure
injection function is maintained during the
time the HPCS injection valve is disabled
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Federal Register / Vol. 71, No. 137 / Tuesday, July 18, 2006 / Notices
during testing. In the event of a design basis
accident during testing, the HPCS [highpressure core spray] system could be
returned to service well within the 14-day
outage time allowed by Technical
Specifications. Additionally, the ability of
the Standby Liquid Coolant (SLC) system to
perform its design safety function would not
be affected because SLC is connected
downstream of the HPCS injection valve.
Therefore, there would be no significant
impact on any accident consequences.
Based on the above, the proposed change
to permit certain DG surveillance tests to be
performed during plant operation will have
no effect on accident probabilities or
consequences. Therefore, the proposed
change does not involve a significant
Increase in the probability or consequences
of an accident previously evaluated.
2. Does the operation of Columbia
Generating Station in accordance with the
proposed amendment create the possibility of
a new or different kind of accident from any
accident previously evaluated?
Response: No.
No new accident causal mechanisms
would be introduced as a result of NRC
approval of this amendment request since no
changes are being made to the plant that
would introduce any new accident causal
mechanisms. Equipment will be operated in
the same configuration with the exception of
the plant mode in which the testing is
conducted. This amendment request does not
impact any plant systems that are accident
initiators; neither does it adversely impact
any accident mitigating systems.
Based on the above, implementation of the
proposed changes would not create the
possibility of a new or different kind of
accident from any accident previously
evaluated.
3. Does the operation of Columbia
Generating Station in accordance with the
proposed amendment involve a significant
reduction in the margin of safety?
Response: No.
Margin of safety is related to the
confidence in the ability of the fission
product barriers to perform their design
functions during and following an accident
situation. These barriers include the fuel
cladding, the reactor coolant system, and the
containment system. The proposed changes
to the testing requirements for the DG do not
affect the operability requirements for the
DG, as verification of such operability will
continue to be performed as required.
Continued verification of operability
supports the capability of the DG to perform
its required function of providing emergency
power to plant equipment that supports or
constitutes the fission product barriers.
Consequently, the performance of these
fission product barriers will not be impacted
by implementation of this proposed
amendment. In addition, the proposed
changes involve no changes to setpoints or
limits established or assumed by the accident
analysis. On this, and the above basis, no
safety margins will be impacted.
Energy Northwest concludes that there is
no significant reduction in the margin of
safety.
VerDate Aug<31>2005
16:25 Jul 17, 2006
Jkt 208001
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: William A.
Horin, Esq., Winston & Strawn, 1700 K
Street, NW., Washington, DC 20006–
3817.
NRC Branch Chief: David Terao.
Florida Power and Light Company,
Docket No. 50–335, St. Lucie Plant, Unit
No. 1, St. Lucie County, Florida
Date of amendment request: April 24,
2006.
Description of amendment request:
The proposed amendment would revise
the Technical Specifications (TSs)
consistent with the NRC-approved
Revision 4 to TS Task Force (TSTF)
Standard TS Change Traveler, TSTF–
449, ‘‘Steam Generator Tube Integrity.’’
The NRC staff issued a notice of
opportunity for comment in the Federal
Register on March 2, 2005 (70 FR
10298), on possible amendments
adopting TSTF–449, including a model
safety evaluation and model no
significant hazards consideration
(NSHC) determination, using the
consolidated line item improvement
process. The NRC staff subsequently
issued a notice of availability of the
models for referencing in license
amendment applications in the Federal
Register on May 6, 2005 (70 FR 24126).
The licensee affirmed the applicability
of the following NSHC determination in
its application dated April 24, 2006.
Basis for proposed no significant
hazards consideration determination: As
required by 10 CFR 50.91(a), an analysis
of the issue of no significant hazards
consideration is presented below:
Criterion 1—The proposed change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
The proposed change requires a SG [Steam
Generator] Program that includes
performance criteria that will provide
reasonable assurance that the SG tubing will
retain integrity over the full range of
operating conditions (including startup,
operation in the power range, hot standby,
cooldown and all anticipated transients
included in the design specification). The SG
performance criteria are based on tube
structural integrity, accident induced
leakage, and operational LEAKAGE.
A[n] SGTR [steam generator tube rupture]
event is one of the design basis accidents that
are analyzed as part of a plant’s licensing
basis. In the analysis of a[n] SGTR event, a
bounding primary to secondary LEAKAGE
rate equal to the operational LEAKAGE rate
limits in the licensing basis plus the
PO 00000
Frm 00061
Fmt 4703
Sfmt 4703
LEAKAGE rate associated with a doubleended rupture of a single tube is assumed.
For other design basis accidents such as
MSLB [main steamline break], rod ejection,
and reactor coolant pump locked rotor the
tubes are assumed to retain their structural
integrity (i.e., they are assumed not to
rupture). These analyses typically assume
that primary to secondary LEAKAGE for all
SGs is 1 gallon per minute or increases to 1
gallon per minute as a result of accident
induced stresses. The accident induced
leakage criterion introduced by the proposed
changes accounts for tubes that may leak
during design basis accidents. The accident
induced leakage criterion limits this leakage
to no more than the value assumed in the
accident analysis.
The SG performance criteria proposed
change[s] to the TS[s] identify the standards
against which tube integrity is to be
measured. Meeting the performance criteria
provides reasonable assurance that the SG
tubing will remain capable of fulfilling its
specific safety function of maintaining
reactor coolant pressure boundary integrity
throughout each operating cycle and in the
unlikely event of a design basis accident. The
performance criteria are only a part of the SG
Program required by the proposed change to
the TS[s]. The program, defined by NEI
[Nuclear Energy Institute] 97–06, Steam
Generator Program Guidelines, includes a
framework that incorporates a balance of
prevention, inspection, evaluation, repair,
and leakage monitoring. The proposed
changes do not, therefore, significantly
increase the probability of an accident
previously evaluated.
The consequences of design basis accidents
are, in part, functions of the DOSE
EQUIVALENT I–131 in the primary coolant
and the primary to secondary LEAKAGE
rates resulting from an accident. Therefore,
limits are included in the plant technical
specifications for operational leakage and for
DOSE EQUIVALENT I–131 in primary
coolant to ensure the plant is operated within
its analyzed condition. The typical analysis
of the limiting design basis accident assumes
that primary to secondary leak rate after the
accident is 1 gallon per minute with no more
than [500 gallons per day or 720 gallons per
day] in any one SG, and that the reactor
coolant activity levels of DOSE
EQUIVALENT I–131 are at the TS values
before the accident.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary coolant chemistry controls. The
proposed approach updates the current TSs
and enhances the requirements for SG
inspections. The proposed change does not
adversely impact any other previously
evaluated design basis accident and is an
improvement over the current TSs.
Therefore, the proposed change does not
affect the consequences of a SGTR accident
and the probability of such an accident is
reduced. In addition, the proposed changes
do not affect the consequences of an MSLB,
rod ejection, or a reactor coolant pump
locked rotor event, or other previously
evaluated accident.
Criterion 2—The proposed change does not
create the possibility of a new or different
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18JYN1
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wwhite on PROD1PC61 with NOTICES
kind of accident from any previously
evaluated.
The proposed performance based
requirements are an improvement over the
requirements imposed by the current
technical specifications. Implementation of
the proposed SG Program will not introduce
any adverse changes to the plant design basis
or postulated accidents resulting from
potential tube degradation. The result of the
implementation of the SG Program will be an
enhancement of SG tube performance.
Primary to secondary LEAKAGE that may be
experienced during all plant conditions will
be monitored to ensure it remains within
current accident analysis assumptions.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary or secondary coolant chemistry
controls. In addition, the proposed change
does not impact any other plant system or
component. The change enhances SG
inspection requirements.
Therefore, the proposed change does not
create the possibility of a new or different
type of accident from any accident
previously evaluated.
Criterion 3—The proposed change does not
involve a significant reduction in the margin
of safety.
The SG tubes in pressurized water reactors
are an integral part of the reactor coolant
pressure boundary and, as such, are relied
upon to maintain the primary system’s
pressure and inventory. As part of the reactor
coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as
a heat transfer surface between the primary
and secondary systems such that residual
heat can be removed from the primary
system. In addition, the SG tubes isolate the
radioactive fission products in the primary
coolant from the secondary system. In
summary, the safety function of an SG is
maintained by ensuring the integrity of its
tubes. Steam generator tube integrity is a
function of the design, environment, and the
physical condition of the tube. The proposed
change does not affect tube design or
operating environment. The proposed change
is expected to result in an improvement in
the tube integrity by implementing the SG
Program to manage SG tube inspection,
assessment, repair, and plugging. The
requirements established by the SG Program
are consistent with those in the applicable
design codes and standards and are an
improvement over the requirements in the
current TSs.
For the above reasons, the margin of safety
is not changed and overall plant safety will
be enhanced by the proposed change to the
TS.
Based upon the reasoning presented
above it appears that the three standards
of 10 CFR 50.92(c) are satisfied.
Therefore, the NRC staff proposes to
determine that the amendment request
involves no significant hazards
consideration.
Attorney for licensee: M.S. Ross,
Attorney, Florida Power & Light, P.O.
Box 14000, Juno Beach, Florida 33408–
0420.
VerDate Aug<31>2005
16:25 Jul 17, 2006
Jkt 208001
NRC Branch Chief: Michael L.
Marshall, Jr.
Florida Power and Light Company,
Docket No. 50–389, St. Lucie Plant, Unit
No. 2, St. Lucie County, Florida
Date of amendment request: May 25,
2006.
Description of amendment request:
The proposed amendment would revise
the Technical Specifications (TSs)
consistent with the NRC-approved
Revision 4 to TS Task Force (TSTF)
Standard TS Change Traveler, TSTF–
449, ‘‘Steam Generator Tube Integrity.’’
The NRC staff issued a notice of
opportunity for comment in the Federal
Register on March 2, 2005 (70 FR
10298), on possible amendments
adopting TSTF–449, including a model
safety evaluation and model no
significant hazards consideration
(NSHC) determination, using the
consolidated line item improvement
process. The NRC staff subsequently
issued a notice of availability of the
models for referencing in license
amendment applications in the Federal
Register on May 6, 2005 (70 FR 24126).
The licensee affirmed the applicability
of the following NSHC determination in
its application dated May 25, 2006.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), an
analysis of the issue of no significant
hazards consideration is presented
below:
Criterion 1—The proposed change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
The proposed change requires a SG [Steam
Generator] Program that includes
performance criteria that will provide
reasonable assurance that the SG tubing will
retain integrity over the full range of
operating conditions (including startup,
operation in the power range, hot standby,
cooldown and all anticipated transients
included in the design specification). The SG
performance criteria are based on tube
structural integrity, accident induced
leakage, and operational LEAKAGE.
A[n] SGTR [steam generator tube rupture]
event is one of the design basis accidents that
are analyzed as part of a plant’s licensing
basis. In the analysis of a[n] SGTR event, a
bounding primary to secondary LEAKAGE
rate equal to the operational LEAKAGE rate
limits in the licensing basis plus the
LEAKAGE rate associated with a doubleended rupture of a single tube is assumed.
For other design basis accidents such as
MSLB [main steamline break], rod ejection,
and reactor coolant pump locked rotor the
tubes are assumed to retain their structural
integrity (i.e., they are assumed not to
rupture). These analyses typically assume
that primary to secondary LEAKAGE for all
SGs is 1 gallon per minute or increases to 1
gallon per minute as a result of accident
PO 00000
Frm 00062
Fmt 4703
Sfmt 4703
40747
induced stresses. The accident induced
leakage criterion introduced by the proposed
changes accounts for tubes that may leak
during design basis accidents. The accident
induced leakage criterion limits this leakage
to no more than the value assumed in the
accident analysis.
The SG performance criteria proposed
change[s] to the TS[s] identify the standards
against which tube integrity is to be
measured. Meeting the performance criteria
provides reasonable assurance that the SG
tubing will remain capable of fulfilling its
specific safety function of maintaining
reactor coolant pressure boundary integrity
throughout each operating cycle and in the
unlikely event of a design basis accident. The
performance criteria are only a part of the SG
Program required by the proposed change to
the TS[s]. The program, defined by NEI
[Nuclear Energy Institute] 97–06, Steam
Generator Program Guidelines, includes a
framework that incorporates a balance of
prevention, inspection, evaluation, repair,
and leakage monitoring. The proposed
changes do not, therefore, significantly
increase the probability of an accident
previously evaluated.
The consequences of design basis accidents
are, in part, functions of the DOSE
EQUIVALENT I–131 in the primary coolant
and the primary to secondary LEAKAGE
rates resulting from an accident. Therefore,
limits are included in the plant technical
specifications for operational leakage and for
DOSE EQUIVALENT I–131 in primary
coolant to ensure the plant is operated within
its analyzed condition. The typical analysis
of the limiting design basis accident assumes
that primary to secondary leak rate after the
accident is 1 gallon per minute with no more
than [500 gallons per day or 720 gallons per
day] in any one SG, and that the reactor
coolant activity levels of DOSE
EQUIVALENT I–131 are at the TS values
before the accident.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary coolant chemistry controls. The
proposed approach updates the current TSs
and enhances the requirements for SG
inspections. The proposed change does not
adversely impact any other previously
evaluated design basis accident and is an
improvement over the current TSs.
Therefore, the proposed change does not
affect the consequences of a SGTR accident
and the probability of such an accident is
reduced. In addition, the proposed changes
do not affect the consequences of an MSLB,
rod ejection, or a reactor coolant pump
locked rotor event, or other previously
evaluated accident.
Criterion 2—The proposed change does not
create the possibility of a new or different
kind of accident from any previously
evaluated.
The proposed performance based
requirements are an improvement over the
requirements imposed by the current
technical specifications. Implementation of
the proposed SG Program will not introduce
any adverse changes to the plant design basis
or postulated accidents resulting from
potential tube degradation. The result of the
implementation of the SG Program will be an
E:\FR\FM\18JYN1.SGM
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Federal Register / Vol. 71, No. 137 / Tuesday, July 18, 2006 / Notices
enhancement of SG tube performance.
Primary to secondary LEAKAGE that may be
experienced during all plant conditions will
be monitored to ensure it remains within
current accident analysis assumptions.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary or secondary coolant chemistry
controls. In addition, the proposed change
does not impact any other plant system or
component. The change enhances SG
inspection requirements.
Therefore, the proposed change does not
create the possibility of a new or different
type of accident from any accident
previously evaluated.
Criterion 3—The proposed change does not
involve a significant reduction in the margin
of safety.
The SG tubes in pressurized water reactors
are an integral part of the reactor coolant
pressure boundary and, as such, are relied
upon to maintain the primary system’s
pressure and inventory. As part of the reactor
coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as
a heat transfer surface between the primary
and secondary systems such that residual
heat can be removed from the primary
system. In addition, the SG tubes isolate the
radioactive fission products in the primary
coolant from the secondary system. In
summary, the safety function of an SG is
maintained by ensuring the integrity of its
tubes. Steam generator tube integrity is a
function of the design, environment, and the
physical condition of the tube. The proposed
change does not affect tube design or
operating environment. The proposed change
is expected to result in an improvement in
the tube integrity by implementing the SG
Program to manage SG tube inspection,
assessment, repair, and plugging. The
requirements established by the SG Program
are consistent with those in the applicable
design codes and standards and are an
improvement over the requirements in the
current TSs.
For the above reasons, the margin of safety
is not changed and overall plant safety will
be enhanced by the proposed change to the
TS.
wwhite on PROD1PC61 with NOTICES
Based upon the reasoning presented
above it appears that the three standards
of 10 CFR 50.92(c) are satisfied.
Therefore, the NRC staff proposes to
determine that the amendment request
involves no significant hazards
consideration.
Attorney for licensee: M.S. Ross,
Attorney, Florida Power & Light, P.O.
Box 14000, Juno Beach, Florida 33408–
0420.
NRC Branch Chief: Michael L.
Marshall, Jr.
Florida Power and Light Company,
Docket Nos. 50–250 and 50–251, Turkey
Point Plant, Units 3 and 4, Miami-Dade
County, Florida
Date of amendment request: April 27,
2006.
Description of amendment request:
The proposed amendment would revise
VerDate Aug<31>2005
16:25 Jul 17, 2006
Jkt 208001
the Technical Specifications (TSs)
consistent with the NRC-approved
Revision 4 to TS Task Force (TSTF)
Standard TS Change Traveler, TSTF–
449, ‘‘Steam Generator Tube Integrity.’’
The NRC staff issued a notice of
opportunity for comment in the Federal
Register on March 2, 2005 (70 FR
10298), on possible amendments
adopting TSTF–449, including a model
safety evaluation and model no
significant hazards consideration
(NSHC) determination, using the
consolidated line item improvement
process. The NRC staff subsequently
issued a notice of availability of the
models for referencing in license
amendment applications in the Federal
Register on May 6, 2005 (70 FR 24126).
The licensee affirmed the applicability
of the following NSHC determination in
its application dated April 27, 2006.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), an
analysis of the issue of no significant
hazards consideration is presented
below:
Criterion 1—The proposed change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
The proposed change requires a SG [Steam
Generator] Program that includes
performance criteria that will provide
reasonable assurance that the SG tubing will
retain integrity over the full range of
operating conditions (including startup,
operation in the power range, hot standby,
cooldown and all anticipated transients
included in the design specification). The SG
performance criteria are based on tube
structural integrity, accident induced
leakage, and operational LEAKAGE.
A[n] SGTR [steam generator tube rupture]
event is one of the design basis accidents that
are analyzed as part of a plant’s licensing
basis. In the analysis of a[n] SGTR event, a
bounding primary to secondary LEAKAGE
rate equal to the operational LEAKAGE rate
limits in the licensing basis plus the
LEAKAGE rate associated with a doubleended rupture of a single tube is assumed.
For other design basis accidents such as
MSLB [main steamline break], rod ejection,
and reactor coolant pump locked rotor the
tubes are assumed to retain their structural
integrity (i.e., they are assumed not to
rupture). These analyses typically assume
that primary to secondary LEAKAGE for all
SGs is 1 gallon per minute or increases to 1
gallon per minute as a result of accident
induced stresses. The accident induced
leakage criterion introduced by the proposed
changes accounts for tubes that may leak
during design basis accidents. The accident
induced leakage criterion limits this leakage
to no more than the value assumed in the
accident analysis.
The SG performance criteria proposed
change[s] to the TS[s] identify the standards
against which tube integrity is to be
measured. Meeting the performance criteria
PO 00000
Frm 00063
Fmt 4703
Sfmt 4703
provides reasonable assurance that the SG
tubing will remain capable of fulfilling its
specific safety function of maintaining
reactor coolant pressure boundary integrity
throughout each operating cycle and in the
unlikely event of a design basis accident. The
performance criteria are only a part of the SG
Program required by the proposed change to
the TS[s]. The program, defined by NEI
[Nuclear Energy Institute] 97–06, Steam
Generator Program Guidelines, includes a
framework that incorporates a balance of
prevention, inspection, evaluation, repair,
and leakage monitoring. The proposed
changes do not, therefore, significantly
increase the probability of an accident
previously evaluated.
The consequences of design basis accidents
are, in part, functions of the DOSE
EQUIVALENT I–131 in the primary coolant
and the primary to secondary LEAKAGE
rates resulting from an accident. Therefore,
limits are included in the plant technical
specifications for operational leakage and for
DOSE EQUIVALENT I–131 in primary
coolant to ensure the plant is operated within
its analyzed condition. The typical analysis
of the limiting design basis accident assumes
that primary to secondary leak rate after the
accident is 1 gallon per minute with no more
than [500 gallons per day or 720 gallons per
day] in any one SG, and that the reactor
coolant activity levels of DOSE
EQUIVALENT I–131 are at the TS values
before the accident.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary coolant chemistry controls. The
proposed approach updates the current TSs
and enhances the requirements for SG
inspections. The proposed change does not
adversely impact any other previously
evaluated design basis accident and is an
improvement over the current TSs.
Therefore, the proposed change does not
affect the consequences of a SGTR accident
and the probability of such an accident is
reduced. In addition, the proposed changes
do not affect the consequences of an MSLB,
rod ejection, or a reactor coolant pump
locked rotor event, or other previously
evaluated accident.
Criterion 2—The proposed change does not
create the possibility of a new or different
kind of accident from any previously
evaluated.
The proposed performance based
requirements are an improvement over the
requirements imposed by the current
technical specifications. Implementation of
the proposed SG Program will not introduce
any adverse changes to the plant design basis
or postulated accidents resulting from
potential tube degradation. The result of the
implementation of the SG Program will be an
enhancement of SG tube performance.
Primary to secondary LEAKAGE that may be
experienced during all plant conditions will
be monitored to ensure it remains within
current accident analysis assumptions.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary or secondary coolant chemistry
controls. In addition, the proposed change
does not impact any other plant system or
component. The change enhances SG
inspection requirements.
E:\FR\FM\18JYN1.SGM
18JYN1
Federal Register / Vol. 71, No. 137 / Tuesday, July 18, 2006 / Notices
Therefore, the proposed change does not
create the possibility of a new or different
type of accident from any accident
previously evaluated.
Criterion 3—The proposed change does not
involve a significant reduction in the margin
of safety.
The SG tubes in pressurized water reactors
are an integral part of the reactor coolant
pressure boundary and, as such, are relied
upon to maintain the primary system’s
pressure and inventory. As part of the reactor
coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as
a heat transfer surface between the primary
and secondary systems such that residual
heat can be removed from the primary
system. In addition, the SG tubes isolate the
radioactive fission products in the primary
coolant from the secondary system. In
summary, the safety function of an SG is
maintained by ensuring the integrity of its
tubes. Steam generator tube integrity is a
function of the design, environment, and the
physical condition of the tube. The proposed
change does not affect tube design or
operating environment. The proposed change
is expected to result in an improvement in
the tube integrity by implementing the SG
Program to manage SG tube inspection,
assessment, repair, and plugging. The
requirements established by the SG Program
are consistent with those in the applicable
design codes and standards and are an
improvement over the requirements in the
current TSs.
For the above reasons, the margin of safety
is not changed and overall plant safety will
be enhanced by the proposed change to the
TS.
Based upon the reasoning presented
above it appears that the three standards
of 10 CFR 50.92(c) are satisfied.
Therefore, the NRC staff proposes to
determine that the amendment request
involves no significant hazards
consideration.
Attorney for licensee: M.S. Ross,
Attorney, Florida Power & Light, P.O.
Box 14000, Juno Beach, Florida 33408–
0420.
NRC Branch Chief: Michael L.
Marshall, Jr.
wwhite on PROD1PC61 with NOTICES
Nine Mile Point Nuclear Station, LLC,
Docket No. 50–220, Nine Mile Point
Nuclear Station Unit No. 1, Oswego
County, New York
Date of amendment request: January
18, 2006.
Description of amendment request:
The proposed amendment would delete
the reference to the hydrogen monitors
in Technical Specification (TS) 3.6.11,
‘‘Accident Monitoring Instrumentation’’
consistent with the NRC-approved
Industry/Technical Specification Task
Force (TSTF) Standard Technical
Specification Change Traveler, TSTF–
447, ‘‘Elimination of Hydrogen
Recombiners and Change to Hydrogen
and Oxygen Monitors.’’
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16:25 Jul 17, 2006
Jkt 208001
The NRC staff issued a notice of
availability of ‘‘Model Application
Concerning Technical Specification
Improvement To Eliminate Hydrogen
Recombiner Requirement, and Relax the
Hydrogen and Oxygen Monitor
Requirements for Light Water Reactors
Using the Consolidated Line Item
Improvement Process (CLIIP)’’, in the
Federal Register on September 25, 2003
(68 FR 55416). The notice included a
model safety evaluation (SE), a model
no significant hazards consideration
(NSHC) determination, and a model
application.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, by confirming the
applicability of the model NSHC
determination to NMP–1 and
incorporating it by reference in its
application. The model NSHC
determination is presented below:
Criterion 1—The Proposed Change Does
Not Involve a Significant Increase in the
Probability or Consequences of an Accident
Previously Evaluated.
The revised 10 CFR 50.44 no longer defines
a design-basis loss-of-coolant accident
(LOCA) hydrogen release, and eliminates
requirements for hydrogen control systems to
mitigate such a release. The installation of
hydrogen recombiners and/or vent and purge
systems required by 10 CFR 50.44(b)(3) was
intended to address the limited quantity and
rate of hydrogen generation that was
postulated from a design-basis LOCA. The
Commission has found that this hydrogen
release is not risk-significant because the
design-basis LOCA hydrogen release does not
contribute to the conditional probability of a
large release up to approximately 24 hours
after the onset of core damage. In addition,
these systems were ineffective at mitigating
hydrogen releases from risk-significant
accident sequences that could threaten
containment integrity.
With the elimination of the design-basis
LOCA hydrogen release, hydrogen [and
oxygen] monitors are no longer required to
mitigate design-basis accidents and,
therefore, the hydrogen monitors do not meet
the definition of a safety-related component
as defined in 10 CFR 50.2. RG [Regulatory
Guide] 1.97 Category 1, is intended for key
variables that most directly indicate the
accomplishment of a safety function for
design-basis accident events. The hydrogen
[and oxygen] monitors no longer meet the
definition of Category 1 in RG 1.97. As part
of the rulemaking to revise 10 CFR 50.44 the
Commission found that Category 3, as
defined in RG 1.97, is an appropriate
categorization for the hydrogen monitors
because the monitors are required to
diagnose the course of beyond design-basis
accidents. [Also, as part of the rulemaking to
revise 10 CFR 50.44, the Commission found
that Category 2, as defined in RG 1.97, is an
appropriate categorization for the oxygen
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40749
monitors, because the monitors are required
to verify the status of the inert containment.]
The regulatory requirements for the
hydrogen [and oxygen] monitors can be
relaxed without degrading the plant
emergency response. The emergency
response, in this sense, refers to the
methodologies used in ascertaining the
condition of the reactor core, mitigating the
consequences of an accident, assessing and
projecting offsite releases of radioactivity,
and establishing protective action
recommendations to be communicated to
offsite authorities. Classification of the
hydrogen monitors as Category 3,
[classification of the oxygen monitors as
Category 2] and removal of the hydrogen [and
oxygen] monitors from TS will not prevent
an accident management strategy through the
use of the SAMGs [severe accident
management guidelines], the emergency plan
(EP), the emergency operating procedures
(EOP), and site survey monitoring that
support modification of emergency plan
protective action recommendations (PARs).
Therefore, the elimination of the hydrogen
recombiner requirements and relaxation of
the hydrogen [and oxygen] monitor
requirements, including removal of these
requirements from TS, does not involve a
significant increase in the probability or the
consequences of any accident previously
evaluated.
Criterion 2—The Proposed Change Does
Not Create the Possibility of a New or
Different Kind of Accident From Any
Previously Evaluated.
The elimination of the hydrogen
recombiner requirements and relaxation of
the hydrogen [and oxygen] monitor
requirements, including removal of these
requirements from TS, will not result in any
failure mode not previously analyzed. The
hydrogen recombiner and hydrogen [and
oxygen] monitor equipment was intended to
mitigate a design-basis hydrogen release. The
hydrogen recombiner and hydrogen [and
oxygen] monitor equipment are not
considered accident precursors, nor does
their existence or elimination have any
adverse impact on the pre-accident state of
the reactor core or post accident confinement
of radionuclides within the containment
building.
Therefore, this change does not create the
possibility of a new or different kind of
accident from any previously evaluated.
Criterion 3—The Proposed Change Does
Not Involve a Significant Reduction in [a]
Margin of Safety.
The elimination of the hydrogen
recombiner requirements and relaxation of
the hydrogen [and oxygen] monitor
requirements, including removal of these
requirements from TS, in light of existing
plant equipment, instrumentation,
procedures, and programs that provide
effective mitigation of and recovery from
reactor accidents, results in a neutral impact
to the margin of safety.
The installation of hydrogen recombiners
and/or vent and purge systems required by
10 CFR 50.44(b)(3) was intended to address
the limited quantity and rate of hydrogen
generation that was postulated from a designbasis LOCA. The Commission has found that
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this hydrogen release is not risk-significant
because the design-basis LOCA hydrogen
release does not contribute to the conditional
probability of a large release up to
approximately 24 hours after the onset of
core damage.
Category 3 hydrogen monitors are adequate
to provide rapid assessment of current
reactor core conditions and the direction of
degradation while effectively responding to
the event in order to mitigate the
consequences of the accident. The intent of
the requirements established as a result of the
TMI [Three Mile Island], Unit 2 accident can
be adequately met without reliance on safetyrelated hydrogen monitors.
[Category 2 oxygen monitors are adequate
to verify the status of an inerted
containment.]
Therefore, this change does not involve a
significant reduction in [a] margin of safety.
[The intent of the requirements established as
a result of the TMI, Unit 2 accident can be
adequately met without reliance on safetyrelated oxygen monitors.] Removal of
hydrogen [and oxygen] monitoring from TS
will not result in a significant reduction in
their functionality, reliability, and
availability.
The NRC staff has reviewed the model
NSHC determination and its
applicability to NMP–1. Based on this
review, the NRC staff proposes to
determine that the amendment request
involves no significant hazards
consideration.
Attorney for licensee: Mark J.
Wetterhahn, Esquire, Winston & Strawn,
1700 K Street, NW., Washington, DC
20006.
NRC Branch Chief: Richard J. Laufer.
Nuclear Management Company, LLC,
Docket Nos. 50–266 and 50–301, Point
Beach Nuclear Plant, Units 1 and 2,
Town of Two Creeks, Manitowoc
County, Wisconsin
wwhite on PROD1PC61 with NOTICES
Date of amendment request: June 6,
2006.
Description of amendment request:
The proposed amendments would
revise the design basis as described in
the Point Beach Nuclear Plant Final
Safety Analysis Report (FSAR) by
incorporating an updated analysis for
satisfying the reactor vessel Charpy
upper-shelf energy requirements of 10
CFR part 50, Appendix G, Section
IV.A.1.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration which is presented below:
1. Would the proposed amendment involve
a significant increase in the probability or
consequences of any accident previously
evaluated?
The proposed change incorporates the
updated analysis for satisfying the reactor
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16:25 Jul 17, 2006
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vessel Charpy upper-shelf energy
requirements of 10 CFR part 50, Appendix G,
Section IV.A.1 into the FSAR. The proposed
change does not adversely affect accident
initiators or precursors nor alter the design
assumptions, conditions, or the manner in
which the plant is operated and maintained.
The proposed change does not alter or
prevent the ability of structures, systems, and
components from performing their intended
function to mitigate the consequences of an
initiating event within the assumed
acceptance limits. The proposed change does
not affect the source term, containment
isolation, or radiological release assumptions
used in evaluating the radiological
consequences of an accident previously
evaluated. Further, the proposed change does
not increase the types or amounts of
radioactive effluent that may be released
offsite, nor significantly increase individual
or cumulative occupational/public radiation
exposures. The proposed change is consistent
with safety analysis assumptions and
resultant consequences. Therefore, it is
concluded that this change does not
significantly increase the probability of
occurrence of an accident previously
evaluated.
2. Would the proposed amendment create
the possibility of a new or different kind of
accident from any accident previously
evaluated?
The proposed change incorporates the
updated analysis for satisfying the reactor
vessel Charpy upper-shelf energy
requirements of 10 CFR part 50, Appendix G,
Section IV.A.1 into the FSAR. The change
does not impose any new or different
requirements or eliminate any existing
requirements. The change does not alter
assumptions made in the safety analysis. The
proposed change is consistent with the safety
analysis assumptions and current plant
operating practice. Therefore, the proposed
change would not create the possibility of a
new or different kind of accident from any
previously evaluated.
3. Would the proposed amendment result
in a significant reduction in a margin of
safety?
The proposed change incorporates the
updated analysis for satisfying the reactor
vessel Charpy upper-shelf energy
requirements of 10 CFR part 50, Appendix G,
Section IV.A.1 into the FSAR. The proposed
change does not alter the manner in which
safety limits, limiting safety system settings
or limiting conditions for operation are
determined. The setpoints at which
protective actions are initiated are not altered
by the proposed change. Therefore, the
proposed amendment does not result in a
significant reduction in a margin of safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: Jonathan Rogoff,
Esquire, Vice President, Counsel &
Secretary, Nuclear Management
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Company, LLC, 700 First Street,
Hudson, WI 54016.
NRC Branch Chief: L. Raghavan.
Omaha Public Power District, Docket
No. 50–285, Fort Calhoun Station, Unit
No. 1, Washington County, Nebraska
Date of amendment request: May 30,
2006.
Description of amendment request:
The proposed amendment would revise
the Fort Calhoun Station, Unit 1 (FCS)
Technical Specification (TS)
requirements related to steam generator
tube integrity. The change is consistent
with NRC-approved Revision 4 to
Technical Specification Task Force
(TSTF) Standard Technical
Specification Change Traveler TSTF–
449, ‘‘Steam Generator Tube Integrity.’’
The availability of this TS improvement
was announced in the Federal Register
on May 6, 2005 (70 FR 24126) as part
of the consolidated line item
improvement process (CLIIP).
Omaha Public Power District (OPPD)
also proposes to change the FCS TS by
deleting the sleeving repair alternative
to plugging for steam generator tubes.
The FCS replacement steam generators
(RSGs) to be installed during the fall of
2006 are manufactured by Mitsubishi
Heavy Industries, Ltd. (MHI). The
change is being requested because OPPD
has determined that the sleeving repair
alternative to plugging will not be used
for the MHI RSGs.
Basis for proposed no significant
hazards consideration determination:
OPPD stated that it had reviewed the
proposed no significant hazards
consideration determination published
on March 2, 2005 (70 FR 10298), as part
of the CLIIP. OPPD has concluded that
the proposed determination presented
in the notice is applicable to FCS and
the determination is incorporated by
reference to satisfy the requirements of
10 CFR 50.91(a). As required by 10 CFR
50.91(a), the licensee has provided its
analysis of the issue of no significant
hazards consideration, which is
presented below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
The elimination from the TS surveillance
requirements of leak tight sleeves as a repair
method alternative to plugging defective
steam generator tubes does not introduce an
initiator to any previously evaluated
accident. The frequency or periodicity of
performance of the remaining surveillance
requirements for steam generator tubes
(including plugged tubes) is not affected by
this change. Elimination of the tube repair
method has no effect on the consequences of
any previously evaluated accident. The
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proposed changes will not prevent safety
systems from performing their accident
mitigation function as assumed in the safety
analysis.
Therefore, this change does not involve a
significant increase in the probability or
consequences of any accident previously
evaluated.
2. Does the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
Response: No.
The proposed change only affects the TS
surveillance requirements. The proposed
change is a result of installation of RSGs. The
proposed change will eliminate a steam
generator tube repair alternative which
cannot be utilized or credited for the RSGs.
This change will not alter assumptions made
in the safety analysis and licensing bases and
will not create new or different systems
interactions.
Therefore, this change does not create the
possibility of a new or different kind of
accident from any previously evaluated.
3. Does the proposed change involve a
significant reduction in a margin of safety?
Response: No.
The proposed change deletes surveillance
requirements for a steam generator tube
repair alternative which will no longer be
necessary or applicable. The remaining TS
steam generator tube surveillance
requirements, including inspection and
plugging requirements, will continue to
maintain the applicable margin of safety.
Therefore, this TS change does not involve
a significant reduction in the margin of
safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: James R.
Curtiss, Esq., Winston & Strawn, 1700 K
Street, NW., Washington, DC 20006–
3817.
NRC Branch Chief: David Terao
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Pacific Gas and Electric Company,
Docket Nos. 50–275 and 50–323, Diablo
Canyon Nuclear Power Plant, Unit Nos.
1 and 2, San Luis Obispo County,
California
Date of amendment requests: May 30,
2006.
Description of amendment requests:
The proposed amendment would revise
the Technical Specifications (TSs) to
adopt NRC-approved Revision 4 to
Technical Specification Task Force
(TSTF) Standard Technical
Specification Change Traveler, TSTF–
449, ‘‘Steam Generator Tube Integrity.’’
The proposed amendment includes
changes to the TS definition of Leakage,
TS 3.4.13, ‘‘RCS [Reactor Coolant
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16:25 Jul 17, 2006
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System] Operational Leakage,’’ TS 5.5.9,
‘‘Steam Generator (SG) Tube
Surveillance Program,’’ TS 5.6.10,
‘‘Steam Generator (SG) Tube Inspection
Report,’’ and adds TS 3.4.17, ‘‘Steam
Generator (SG) Tube Integrity.’’ The
proposed changes are necessary in order
to implement the guidance for the
industry initiative on NEI 97–06,
‘‘Steam Generator Program Guidelines.’’
The NRC staff issued a notice of
opportunity for comment in the Federal
Register on March 2, 2005 (70 FR
10298), on possible amendments
adopting TSTF–449, including a model
safety evaluation and model no
significant hazards consideration
(NSHC) determination, using the
consolidated line item improvement
process. The NRC staff subsequently
issued a notice of availability of the
models for referencing in license
amendment applications in the Federal
Register on May 6, 2005 (70 FR 24126).
The licensee affirmed the applicability
of the following NSHC determination in
its application dated May 30, 2005.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), an
analysis of the issue of no significant
hazards consideration is presented
below:
Criterion 1—The Proposed Change Does
Not Involve a Significant Increase in the
Probability or Consequences of an Accident
Previously Evaluated.
The proposed change requires an SG
Program that includes performance criteria
that will provide reasonable assurance that
the SG tubing will retain integrity over the
full range of operating conditions (including
startup, operation in the power range, hot
standby, cooldown and all anticipated
transients included in the design
specification). The SG performance criteria
are based on tube structural integrity,
accident-induced leakage, and operational
LEAKAGE.
A steam generator tube rupture (SGTR)
event is one of the design-basis accidents that
are analyzed as part of a plant’s licensing
basis. In the analysis of an SGTR event, a
bounding primary to secondary LEAKAGE
rate equal to the operational LEAKAGE rate
limits in the licensing basis plus the
LEAKAGE rate associated with a doubleended rupture of a single tube is assumed.
For other design-basis accidents such as a
main steamline break (MSLB), rod ejection,
and reactor coolant pump locked rotor, the
tubes are assumed to retain their structural
integrity (i.e., they are assumed not to
rupture). These analyses typically assume
that primary to secondary LEAKAGE for all
SGs are 1 gallon per minute or increases to
1 gallon per minute as a result of accidentinduced stresses. The accident-induced
leakage criterion introduced by the proposed
changes accounts for tubes that may leak
during design-basis accidents. The accidentinduced leakage criterion limits this leakage
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40751
to no more than the value assumed in the
accident analysis.
The SG performance criteria proposed
change to the TS identify the standards
against which tube integrity is to be
measured. Meeting the performance criteria
provides reasonable assurance that the SG
tubing will remain capable of fulfilling its
specific safety function of maintaining
reactor coolant pressure boundary integrity
throughout each operating cycle and in the
unlikely event of a design-basis accident. The
performance criteria are only a part of the SG
Program required by the proposed change to
the TS. The program, defined by NEI 97–06,
‘‘Steam Generator Program Guidelines,’’
includes a framework that incorporates a
balance of prevention, inspection, evaluation,
repair, and leakage monitoring. The proposed
changes do not, therefore, significantly
increase the probability of an accident
previously evaluated.
The consequences of design-basis
accidents are, in part, functions of the DOSE
EQUIVALENT I–131 in the primary coolant
and the primary to secondary LEAKAGE
rates resulting from an accident. Therefore,
limits are included in the plant technical
specifications for operational leakage and for
DOSE EQUIVALENT I–131 in primary
coolant to ensure the plant is operated within
its analyzed condition. The typical analysis
of the limiting design-basis accident assumes
that primary to secondary leak rate after the
accident is 1 gallon per minute with no more
than [500 gallons per day or 720 gallons per
day] in any one SG, and that the reactor
coolant activity levels of DOSE
EQUIVALENT I–131 are at the TS values
before the accident.
The proposed change does not affect the
design of the SGs, their method of operation,
or primary coolant chemistry controls. The
proposed approach updates the current TSs
and enhances the requirements for SG
inspections. The proposed change does not
adversely impact any other previously
evaluated design-basis accident and is an
improvement over the current TSs.
Therefore, the proposed change does not
affect the consequences of an SGTR accident
and the probability of such an accident is
reduced. In addition, the proposed changes
do not affect the consequences of an MSLB,
rod ejection, or a reactor coolant pump
locked rotor event, or other previously
evaluated accident.
Criterion 2—The Proposed Change Does
Not Create the Possibility of a New or
Different Kind of Accident From Any
Previously Evaluated.
The proposed performance-based
requirements are an improvement over the
requirements imposed by the current
technical specifications. Implementation of
the proposed SG Program will not introduce
any adverse changes to the plant design basis
or postulated accidents resulting from
potential tube degradation. The result of the
implementation of the SG Program will be an
enhancement of SG tube performance.
Primary to secondary LEAKAGE that may be
experienced during all plant conditions will
be monitored to ensure it remains within
current accident analysis assumptions.
The proposed change does not affect the
design of the SGs, their method of operation,
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or primary or secondary coolant chemistry
controls. In addition, the proposed change
does not impact any other plant system or
component. The change enhances SG
inspection requirements.
Therefore, the proposed change does not
create the possibility of a new or different
type of accident from any accident
previously evaluated.
Criterion 3—The Proposed Change Does
Not Involve a Significant Reduction in the
Margin of Safety.
The SG tubes in pressurized-water reactors
are an integral part of the the primary
system’s pressure and inventory. As part of
the reactor coolant pressure boundary, the SG
tubes are unique in that they are also relied
upon as a heat transfer surface between the
primary and secondary systems such that
residual heat can be removed from the
primary system. In addition, the SG tubes
isolate the radioactive fission products in the
primary coolant from the secondary system.
In summary, the safety function of an SG is
maintained by ensuring the integrity of its
tubes.
Steam generator tube integrity is a function
of the design, environment, and the physical
condition of the tube. The proposed change
does not affect tube design or operating
environment. The proposed change is
expected to result in an improvement in the
tube integrity by implementing the SG
Program to manage SG tube inspection,
assessment, repair, and plugging. The
requirements established by the SG Program
are consistent with those in the applicable
design codes and standards and are an
improvement over the requirements in the
current TSs.
For the above reasons, the margin of safety
is not changed and overall plant safety will
be enhanced by the proposed change to the
TS.
wwhite on PROD1PC61 with NOTICES
The NRC staff proposes to determine
that the amendment requests involve no
significant hazards consideration.
Attorney for licensee: Richard F.
Locke, Esq., Pacific Gas and Electric
Company, P.O. Box 7442, San
Francisco, California 94120.
NRC Branch Chief: David Terao.
PSEG Nuclear LLC, Docket Nos. 50–272
and 50–311, Salem Nuclear Generating
Station, Unit Nos. 1 and 2, Salem
County, New Jersey
Date of amendment request: May 1,
2006.
Description of amendment request:
The proposed amendment would
eliminate the requirement for a power
range, neutron flux, high negative rate
trip and delete the references to this trip
as functional Unit 4 in Salem
Generating Station (Salem) Unit Nos. 1
and 2 Technical Specification (TS)
Table 2.2–1, ‘‘Reactor Trip System
Instrumentation Trip Setpoints,’’ TS
Table 3.3–1, ‘‘Reactor Trip System
Instrumentation,’’ TS Table 3.3–2,
‘‘Reactor Trip System Instrumentation
Response Times,’’ and TS Table 4.3–1,
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16:25 Jul 17, 2006
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‘‘Reactor Trip System Instrumentation
Surveillance Requirements [SRs].’’ The
proposed changes are consistent with
the methodology presented in the
Westinghouse Topical Report WCAP–
11394–P–A, ‘‘Methodology for the
Analysis of the Dropped Rod Event,’’
which has been reviewed by the NRC
and found acceptable for referencing in
license applications. The amendment
also would involve the correction of
errata in the TS for Salem Unit Nos. 1
and 2.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
The elimination of the Power Range,
Neutron Flux, Negative Rate trip does not
increase the probability or consequences of
reactor core damage accidents resulting from
Rod Cluster Control Assembly (RCCA)
Misalignment events previously analyzed.
The safety functions of other safety-related
systems and components have not been
altered. All other Reactor Trip System
protection functions are not impacted by the
elimination of the requirement for a Power
Range, Neutron Flux, High Negative Rate
trip. The Power Range, Neutron Flux, High
Negative Rate trip circuitry detects and
responds to negative reactivity insertion due
to RCCA misoperation events, should they
occur. Therefore, the Power Range, Neutron
Flux, High Negative Rate trip is not assumed
in the initiation of such events. The
consequences of accidents previously
evaluated in the Salem Generating Station
(Salem) Updated Final Safety Analysis
Report (UFSAR) are unaffected by the
proposed changes because no change to any
equipment response or accident mitigation
scenario has resulted. The proposed changes
do not modify the RCCAs or change the
acceptance criteria for departure from
nucleate boiling (DNB). The TS change
reflects analysis described in the UFSAR and
cycle-specific analysis performed each fuel
cycle.
The proposed revisions to Salem Unit 1
Index page XII, Salem Unit 1 TS 4.2.2.2,
Salem Unit 2 TS 4.2.2.2, Salem Unit 1 TS
Table 3.3–2, Salem Unit 2 SR number for
boron concentration on page 3/4 9-1, Salem
Unit 1 TS 6.9.1.5.a, and Salem Unit 1 TS
6.9.1.5.b contain changes administrative in
nature that correct errors and do not affect
the intent of any TS requirements.
Therefore, the proposed changes do not
involve a significant increase in the
probability or radiological consequences of
an accident previously evaluated.
2. Does the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
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Response: No.
The elimination of the Power Range,
Neutron Flux, High Negative Rate trip does
not create the possibility of a new or different
kind of accident from any accident
previously evaluated in the UFSAR. No new
accident scenarios, failure mechanisms, or
limiting single failures are introduced as a
result of the proposed changes. The proposed
changes do not challenge the performance or
integrity of the RCCAs or any other safetyrelated system. The proposed changes will
have no adverse effect on the availability,
operability, or performance of the safetyrelated systems and components assumed to
actuate in the event of a design basis accident
(DBA) or transient. It has been demonstrated
that the Power Range, Neutron Flux, High
Negative Rate trip can be eliminated by the
NRC approved methodology described in
WCAP–11394–P. The Salem fuel cycle
specific analyses have confirmed that for a
dropped RCCA event, no direct reactor trip
or automatic power reduction is required to
meet the DNB limits for this Condition II,
‘‘Fault of Moderate Frequency,’’ event. The
Power Range, Neutron Flux, High Negative
Rate trip is not credited either as a primary
or backup mitigation feature for any other
UFSAR event.
The proposed revisions to Salem Unit 1
Index page XII, Salem Unit 1 TS 4.2.2.2,
Salem Unit 2 TS 4.2.2.2, Salem Unit 1 TS
Table 3.3–2, Salem Unit 2 SR number for
boron concentration on page 3/4 9-1, Salem
Unit 1 TS 6.9.1.5.a, and Salem Unit 1 TS
6.9.1.5.b contain changes administrative in
nature that correct errors and do not affect
the intent of any TS requirements.
Therefore, the proposed changes do not
create the possibility of a new or different
kind of accident from any accident
previously evaluated.
3. Does the proposed change involve a
significant reduction in a margin of safety?
Response: No.
The margin of safety is the difference
between the DNB acceptance limit and the
failure of the fuel rod cladding. The Salem
fuel cycle specific analyses have confirmed
that for a dropped RCCA event, DNB limits
are not exceeded with the proposed changes.
Conformance to the licensing basis
acceptance criteria for DBAs and transients
with the elimination of the Power Range,
Neutron Flux, High Negative Rate trip is
demonstrated and the DNB limits are not
exceeded when the NRC approved
methodology of WCAP–11394–P is applied.
The margin of safety associated with the
licensing basis acceptance criteria for any
postulated accident is unchanged.
The proposed revisions to Salem Unit 1
Index page XII, Salem Unit 1 TS 4.2.2.2,
Salem Unit 2 TS 4.2.2.2, Salem Unit 1 TS
Table 3.3–2, Salem Unit 2 SR number for
boron concentration on page 3/4 9-1, Salem
Unit 1 TS 6.9.1.5.a, and Salem Unit 1 TS
6.9.1.5.b contain changes administrative in
nature that correct errors and do not affect
the intent of any TS requirements.
Therefore, the proposed changes do not
involve a significant reduction in a margin of
safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
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review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: Jeffrie J. Keenan,
Esquire, Nuclear Business Unit–N21,
P.O. Box 236, Hancocks Bridge, NJ
08038.
NRC Branch Chief: Darrell J. Roberts.
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PSEG Nuclear LLC, Docket Nos. 50–272
and 50–311, Salem Nuclear Generating
Station, Unit Nos. 1 and 2, Salem
County, New Jersey
Date of amendment request: May 1,
2006.
Description of amendment request:
The amendment would move the main
steamline discharge (safety valves and
atmospheric dumps) radiation monitors
(R46) from the radiation monitoring
instrumentation Technical Specification
(TS) 3.3.3.1, to the accident monitoring
TS 3.3.3.7. The purpose of the R46
monitors is to provide continuous
monitoring of high-level, post-accident
releases of radioactive noble gases;
therefore, relocation to TS 3.3.3.7 is
appropriate. In addition, TS definition
1.31, ‘‘Source Checks,’’ would be
modified to allow different methods to
comply with the source check
requirement. This change would affect
the remaining instruments in TS 3.3.3.1,
and would allow for appropriate testing
consistent with the technology of the
existing detectors, and replacement
detectors in the future.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
The proposed change to the R46 monitors
presents no change in the probability or the
consequence of an accident, since the
monitors are used post-accident for the
monitoring of high-level releases of
radioactive noble gases.
Relocation of the R46 monitors to the
accident monitoring TS 3.3.3.7 is appropriate
for the function of the monitors. The R46
monitors are designed to meet the
requirements of NUREG–0737 Il.F.1 and the
intent of RG [Regulatory Guide] 1.97. The
monitor’s alarm function is used in the EOPs
[Emergency Operating Procedures] to identify
a Steam Generator Tube Rupture (SGTR)
event EOP entry point and to identify which
SG [steam generator] has ruptured. The
relocation of the monitor to TS 3.3.3.7 has no
affect on the function of the monitor.
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The proposed change to the definition of
TS 1.31 also does not impact the accident
analyses in any manner. The qualitative
assessment of monitor response will continue
to be performed verifying monitor
operability.
2. Does the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
Response: No.
The proposed relocation of the R46
monitors is primarily administrative in
nature; there will be no change in the
function of the monitors. No new accident
scenarios, failure mechanisms, or limiting
single failures are introduced as a result of
the proposed changes. Post accident
monitoring instrumentation is not associated
with the initiation of an accident.
The proposed change to the definition of
TS 1.31 also does not create a new or
different kind of accident. The qualitative
assessment of monitor response will continue
to be performed verifying monitor
operability.
3. Does the proposed change involve a
significant reduction in the margin of safety?
Response: No.
The proposed change to relocate the R46
monitors does not alter the manner in which
safety limits, limiting safety systems settings
or limiting conditions for operation are
determined. The proposed change will not
alter any assumptions, initial conditions or
results specified in any accident analysis.
There is no change in the R46 monitor alarm
setpoint.
The proposed change to the TS definition
of SOURCE CHECK does not alter the basic
requirement that a qualitative assessment of
the monitor response be performed; therefore
the operability of the monitor will continue
to be verified.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: Jeffrie J. Keenan,
Esquire, Nuclear Business Unit–N21,
P.O. Box 236, Hancocks Bridge, NJ
08038.
NRC Branch Chief: Darrell J. Roberts.
PSEG Nuclear LLC, Docket No. 50–311,
Salem Nuclear Generating Station, Unit
No. 2, Salem County, New Jersey
Date of amendment request: April 6,
2006.
Description of the amendment
request: The proposed amendment
changes the existing steam generator
(SG) tube surveillance program to one
that is consistent with the program
proposed by the Technical Specification
Task Force (TSTF) in TSTF–449. These
changes revise Technical Specification
(TS) 1.15, ‘‘Identified Leakage,’’ TS 1.21,
‘‘Pressure Boundary Leakage,’’ TS
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3/4.4.6, ‘‘Steam Generator (SG) Tube
Integrity,’’ and TS 3/4.4.7.2,
‘‘Operational Leakage,’’ and add new
administrative TS 6.8.4.i, ‘‘Steam
Generator (SG) Program,’’ and TS
6.9.1.10, ‘‘Steam Generator Tube
Inspection Report.’’ Other editorial
changes were also made.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
The proposed change requires a Steam
Generator Program that includes performance
criteria that will provide reasonable
assurance that the steam generator (SG)
tubing will retain integrity over the full range
of operating conditions (including startup,
operation in the power range, hot standby,
cool down and all anticipated transients
included in the design specification). The SG
performance criteria are based on tube
structural integrity, accident induced
leakage, and operational leakage.
The structural integrity performance
criterion is:
All in-service steam generator tubes shall
retain structural integrity over the full range
of normal operating conditions (including
startup, operation in the power range, hot
standby, and cool down and all anticipated
transients included in the design
specification) and design basis accidents.
This includes retaining a safety factor of 3.0
against burst under normal steady state full
power operation primary-to-secondary
pressure differential and a safety factor of 1.4
against burst applied to the design basis
accident primary-to-secondary pressure
differentials. Apart from the above
requirements, additional loading conditions
associated with the design basis accidents, or
combination of accidents in accordance with
the design and licensing basis, shall also be
evaluated to determine if the associated loads
contribute significantly to burst or collapse.
In the assessment of tube integrity, those
loads that do significantly affect burst or
collapse shall be determined and assessed in
combination with the loads due to pressure
with a safety factor of 1.2 on the combined
primary loads and 1.0 on axial secondary
loads.
The accident induced leakage performance
criterion is:
The primary-to-secondary accident
induced leakage rate for any design basis
accidents, other than a SG tube rupture, shall
not exceed the leakage rate assumed in the
accident analysis in terms of total leakage
rate for all SGs and leakage rate for an
individual SG. Leakage is not to exceed 1
gpm [gallon per minute] per SG.
The operational leakage performance
criterion is:
The reactor coolant system operational
primary-to-secondary leakage through any
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one SG shall be limited to 150 gallons per
day.
A steam generator tube rupture (SGTR)
event is one of the design basis accidents that
are analyzed as part of a plant’s licensing
basis. In the analysis of an SGTR event, a
bounding primary-to-secondary leakage rate
equal to the operational leakage rate limits in
the licensing basis plus the leakage rate
associated with a double-ended rupture of a
single tube is assumed.
For other design basis accidents such as
main steam line break (MSLB), rod ejection,
and reactor coolant pump locked rotor, the
tubes are assumed to retain their structural
integrity (i.e., they are assumed not to
rupture). These analyses assume that
primary-to-secondary leakage for all SGs is 1
gallon per minute or increases to 1 gallon per
minute as a result of accident-induced
stresses. The accident induced leakage
criterion retained by the proposed changes
accounts for tubes that may leak during
design basis accidents. The accident induced
leakage criterion limits this leakage to no
more than the value assumed in the accident
analysis.
The SG performance criteria proposed as
part of these TS changes identify the
standards against which tube integrity is to
be measured. Meeting the performance
criteria provides reasonable assurance that
the SG tubing will remain capable of
fulfilling its specific safety function of
maintaining reactor coolant pressure
boundary integrity throughout each operating
cycle and in the unlikely event of a design
basis accident. The performance criteria are
only a part of the Steam Generator Program
required by the proposed addition of TS
6.8.4.i. The program defined by NEI [Nuclear
Energy Institute] 97–06 includes a framework
that incorporates a balance of prevention,
inspection, evaluation, repair, and leakage
monitoring.
The consequences of design basis accidents
are, in part, functions of the DOSE
EQUIVALENT I–131 in the primary coolant
and the primary-to-secondary leakage rates
resulting from an accident. Therefore, limits
are included in the Salem TS for operational
leakage and for DOSE EQUIVALENT I–131 in
primary coolant to ensure the plant is
operated within its analyzed condition. The
typical analysis of the limiting design basis
accident assumes that primary-to-secondary
leak rate after the accident is 1 gallon per
minute with no more than 500 gallons per
day through any one SG, and that the reactor
coolant activity levels of DOSE
EQUIVALENT I–131 are at the TS values
before the accident.
The proposed change that allows SR
[Surveillance Requirement] 4.4.7.2.1.d to not
be performed until 12 hours after
establishment of steady state operation is
consistent with NUREG 1431, ‘‘Standard
Technical Specifications, Westinghouse
Plants’’, and ensures the surveillance
requirement is appropriate for the LCO
[Limiting Condition for Operation].
The proposed change does not affect the
design of the SGs, their method of operation,
or primary coolant chemistry controls. The
proposed approach updates the current TS
and enhances the requirements for SG
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inspections. The proposed change does not
adversely impact any other previously
evaluated design basis accident and is an
improvement over the current TS.
Therefore, the proposed changes do not
affect the consequences of an SGTR accident
and the probability of such an accident is
reduced.
In addition, the proposed changes do not
affect the probabilities or consequences of an
MSLB, rod ejection, or a reactor coolant
pump locked rotor event.
2. Does the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
Response: No.
The proposed performance based
requirements are an improvement over the
requirements imposed by the current TS.
Implementation of the proposed Steam
Generator Program will not introduce any
adverse changes to the plant design basis or
postulated accidents resulting from potential
tube degradation. The result of the
implementation of the Steam Generator
Program will be an enhancement of SG tube
performance. Primary-to-secondary leakage
that may be experienced during all plant
conditions will be monitored to ensure it
remains within current accident analysis
assumptions.
The proposed changes do not affect the
design of the SGs, their method of operation,
or primary or secondary coolant chemistry
controls. In addition, the proposed change
does not impact any other plant system or
component. The change enhances SG
inspection requirements.
The proposed change that allows SR
4.4.7.2.1.d to not be performed until 12 hours
after establishment of steady state operation
is consistent with NUREG 1431, ‘‘Standard
Technical Specifications, Westinghouse
Plants’’, and ensures the surveillance
requirement is appropriate for the LCO.
Therefore, the proposed changes do not
create the possibility of a new or different
kind of accident from any previously
evaluated.
3. Does the proposed change involve a
significant reduction in a margin of safety?
Response: No.
The SG tubes in pressurized water reactors
are an integral part of the reactor coolant
pressure boundary and, as such, are relied
upon to maintain the primary system’s
pressure and inventory. As part of the reactor
coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as
a heat transfer surface between the primary
and secondary systems such that residual
heat can be removed from the primary
system. In addition, the SG tubes also isolate
the radioactive fission products in the
primary coolant from the secondary system.
In summary, the safety function of a SG is
maintained by ensuring the integrity of its
tubes.
Steam generator tube integrity is a function
of the design, environment, and the physical
condition of the tube. The proposed change
does not affect tube design or operating
environment. The proposed change is
expected to result in an improvement in the
tube integrity by implementing the Steam
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Generator Program to manage SG tube
inspection, assessment, repair and plugging.
The requirements established by the Steam
Generator Program are consistent with those
in the applicable design codes and standards
and are an improvement over the
requirements in the current TS.
The proposed change that allows SR
4.4.7.2.1.d to not be performed until 12 hours
after establishment of steady state operation
is consistent with NUREG 1431, ‘‘Standard
Technical Specifications, Westinghouse
Plants’’, and ensures the surveillance
requirement is appropriate for the LCO.
For the above reasons, the margin of safety
is not changed and overall plant safety will
be enhanced by the proposed changes to the
TS.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: Jeffrie J. Keenan,
Esquire, Nuclear Business Unit—N21,
P.O. Box 236, Hancocks Bridge, NJ
08038.
NRC Branch Chief: Darrell J. Roberts.
Southern California Edison Company, et
al., Docket Nos. 50–361 and 50–362,
San Onofre Nuclear Generating Station,
Units 2 and 3, San Diego County,
California
Date of amendment requests: June 2,
2006.
Description of amendment requests:
The amendment proposes to revise
Technical Specification (TS) 3.8.1, ‘‘AC
[alternating current] Sources—
Operating,’’ and TS 3.8.3, ‘‘Diesel Fuel
Oil, Lube Oil, and Starting Air,’’ to
increase the required amount of stored
diesel fuel oil to support a change to
Ultra Low Sulfur Diesel fuel from
California diesel fuel presently in use.
This change in the type of fuel oil is
mandated by California air pollution
control regulations.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
This proposed change increases the
minimum amount of stored diesel fuel. The
change supports the use of Ultra Low Sulfur
Diesel (ULSD) fuel rather than the existing
California Air Resources Board diesel fuel as
mandated by California air pollution control
regulations (Title 13 California Code of
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Regulations Division 3, Chapter 5, Article 2,
Sections 2280–2285).
Technical Specification (TS) 3.8.3, ‘‘Diesel
Fuel Oil, Lube Oil, and Starting Air,’’
requires that each diesel generator have
sufficient fuel to operate for a period of 7
days, while the diesel generator (DG) is
supplying maximum post Loss of Coolant
Accident (LOCA) load demand.
Because the Lower Heating Value (LHV)
per gallon of ULSD fuel is less than that of
existing diesel fuel, it was necessary to recalculate the amount of fuel required to
supply necessary loads for the required time
periods. For Modes 1 through 4, the resulting
minimum volumes of ULSD fuel are 48,400
gallons and 41,800 gallons for the 7-day and
6-day fuel supply, respectively. For Modes 5
and 6, the required volumes of ULSD fuel are
43,600 gallons and 37,400 gallons for a 7-day
supply and a 6-day supply, respectively.
The DGs and the associated support
systems such as the fuel oil storage and
transfer systems are designed to mitigate
accidents and are not accident initiators.
Increasing the minimum volumes of stored
fuel in the storage and day tanks will not
result in a significant increase in the
probability of any accident previously
evaluated.
Following implementation of this proposed
change, there will be no change in the ability
of the diesel generators to supply maximum
post-LOCA load demand for 7 days. The
proposed minimum volumes of fuel, 48,400
gallons and 41,800 gallons, ensure that a 7day and [a] 6-day supply of fuel, respectively,
are available in Modes 1 through 4. The
proposed minimum volumes of fuel, 43,600
gallons and 37,400 gallons, ensure that a 7day and a 6-day supply, respectively, of fuel
is available in Modes 5 and 6. This is
identical to the current requirements, except
for the increased volume of fuel required due
to the decreased heat content of the ULSD
fuel. Therefore, this change will not result in
a significant increase in the consequences of
any accident previously evaluated.
Therefore, the proposed change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
2. Does the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
Response: No.
Following this change, the diesel
generators will still be able to supply
maximum post-LOCA load demand. The
current 7-day and 6-day fuel supply
requirements will be maintained following
this change. The new required fuel oil
volumes are within the capacities of the fuel
oil storage tanks.
Therefore, this proposed change will not
create the possibility of a new or different
kind of accident from any accident that has
been previously evaluated.
3. Does the proposed change involve a
significant reduction in a margin of safety?
Response: No.
The Bases to TS 3.8.3 state that ‘‘[e]ach
diesel generator (DG) is provided with a
storage tank having a fuel oil capacity
sufficient to operate that diesel for a period
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of 7 days, while the DG is supplying
maximum post loss of coolant accident load
demand.’’ When the fuel oil tank level is less
than required to support the 7-day of
operation, the required action depends on
whether or not a 6-day supply of fuel is
available.
The proposed tank level limits will
maintain these 7-day and 6-day fuel supply
requirements in all operating Modes
following changeout to ULSD fuel.
Therefore, the proposed change does not
involve a significant reduction in a margin of
safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment requests involve no
significant hazards consideration.
Attorney for licensee: Douglas K.
Porter, Esquire, Southern California
Edison Company, 2244 Walnut Grove
Avenue, Rosemead, California 91770.
NRC Branch Chief: David Terao.
Union Electric Company, Docket No.
50–483, Callaway Plant, Unit 1,
Callaway County, Missouri
Date of amendment request: May 25,
2006.
Description of amendment request:
The amendment would revise the
Technical Specifications (TSs) to adopt
NRC-approved Revision 4 to Technical
Specification Task Force (TSTF)
Standard Technical Specification
Change Traveler TSTF–372, ‘‘Addition
of LCO [Limiting Condition for
Operation] 3.0.8, Inoperability of
Snubbers.’’ The amendment would add
(1) a new LCO 3.0.8 addressing when
one or more required snubbers are
unable to perform their associated
support function(s) (i.e., the snubber is
inoperable) and (2) a reference to LCO
3.0.8 in LCO 3.0.1 on when LCOs shall
be met.
The NRC staff issued a notice of
opportunity for comment in the Federal
Register on November 24, 2004 (69 FR
68412), on possible license amendments
adopting TSTF–372 using the NRC’s
consolidated line item improvement
process (CLIIP) for amending licensee’s
TSs, which included a model safety
evaluation (SE) and model no
significant hazards consideration
(NSHC) determination. The NRC staff
subsequently issued a notice of
availability of the models for referencing
in license amendment applications in
the Federal Register on May 4, 2005 (70
FR 23252), which included the
resolution of public comments on the
model SE. The May 4, 2005, notice of
availability referenced the November 24,
2004, notice. The licensee has affirmed
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the applicability of the following NSHC
determination in its application.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), an
analysis of the issue of no significant
hazards consideration is presented
below:
Criterion 1—Does the proposed change
involve a significant increase in the
probability or consequences of an accident
previously evaluated?
The proposed change allows a delay time
for entering a supported system technical
specification (TS) when the inoperability is
due solely to an inoperable snubber if risk is
assessed and managed. The postulated
seismic event requiring snubbers is a lowprobability occurrence and the overall TS
system safety function would still be
available for the vast majority of anticipated
challenges. Therefore, the probability of an
accident previously evaluated is not
significantly increased, if at all. The
consequences of an accident while relying on
allowance provided by proposed LCO 3.0.8
are no different than the consequences of an
accident while relying on the TS required
actions in effect without the allowance
provided by proposed LCO 3.0.8. Therefore,
the consequences of an accident previously
evaluated are not significantly affected by
this change. The addition of a requirement to
assess and manage the risk introduced by this
change will further minimize possible
concerns. Therefore, this change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
Criterion 2—Does the proposed change
create the possibility of a new or different
kind of accident from any accident
previously evaluated?
The proposed change does not involve a
physical alteration of the plant (no new or
different type of equipment will be installed).
Allowing delay times for entering [a]
supported system TS when inoperability is
due solely to inoperable snubbers, if risk is
assessed and managed, will not introduce
new failure modes or effects and will not, in
the absence of other unrelated failures, lead
to an accident whose consequences exceed
the consequences of accidents previously
evaluated. The addition of a requirement to
assess and manage the risk introduced by this
change will further minimize possible
concerns. Thus, this change does not create
the possibility of a new or different kind of
accident from an accident previously
evaluated.
Criterion 3—Does the proposed change
involve a significant reduction in the margin
of safety?
The proposed change allows a delay time
for entering a supported system TS when the
inoperability is due solely to an inoperable
snubber, if risk is assessed and managed. The
postulated seismic event requiring snubbers
is a low-probability occurrence and the
overall TS system safety function would still
be available for the vast majority of
anticipated challenges. The risk impact of the
proposed TS changes was assessed following
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the three-tiered approach recommended in
[NRC] RG [Regulatory Guide] 1.177. A
bounding risk assessment was performed to
justify the proposed TS changes. This
application of LCO 3.0.8 is predicated upon
the licensee’s performance of a risk
assessment and the management of plant risk
[, which is required by the proposed TS
3.0.8]. The net change to the margin of safety
is insignificant. Therefore, this change does
not involve a significant reduction in a
margin of safety.
The NRC staff proposes to determine
that the amendment request involves no
significant hazards consideration.
Attorney for licensee: John O’Neill,
Esq., Pillsbury Winthrop Shaw Pittman
LLP, 2300 N Street, NW., Washington,
DC 20037.
NRC Branch Chief: David Terao.
Union Electric Company, Docket No.
50–483, Callaway Plant, Unit 1,
Callaway County, Missouri
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Date of amendment request: May 25,
2006.
Description of amendment request:
The amendment would revise Technical
Specifications 3.1.7, ‘‘Rod Position
Indication,’’ 3.2.1, ‘‘Heat Flux Hot
Channel Factor (FCQ(Z)) (FQ
Methodology),’’ 3.2.4, ‘‘Quadrant Power
Tilt Ratio (QPTR),’’ and 3.3.1, ‘‘Reactor
Trip System (RTS) Instrumentation.’’
The proposed changes are to allow use
of the Westinghouse proprietary
computer code, the Best Estimate
Analyzer for Core Operations—Nuclear
(BEACON). The new BEACON power
distribution monitoring system (PDMS)
would augment the functional
capability of the neutron flux mapping
system for the purposes of power
distribution surveillances at the
Callaway Plant. Certain required
actions, for when a limiting condition
for operation is not met, and certain
surveillance requirements are being
changed to refer to power distribution
measurements or measurement
information of the core.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
consideration, which is presented
below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
The PDMS performs continuous core
power distribution monitoring with data
input from existing plant instrumentation.
This system utilizes an NRC-approved
Westinghouse proprietary computer code,
i.e., Best Estimate Analyzer for Core
Operations µ Nuclear (BEACON), to provide
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data reduction for incore flux maps, core
parameter analysis, load follow operation
simulation, and core predication. The PDMS
does not provide any protection or control
system function. Fission product barriers are
not impacted by these proposed changes. The
proposed changes occurring with PDMS will
not result in any additional challenges to
plant equipment that could increase the
probability of any previously evaluated
accident. The changes associated with the
PDMS do not affect plant systems such that
their function in the control of radiological
consequences is adversely affected. These
proposed changes will therefore not affect the
mitigation of the radiological consequences
of any accident described in the Final Safety
Analysis Report (FSAR) [for the Callaway
Plant].
Use of the PDMS supports maintaining the
core power distribution within required
limits. Further continuous on-line
monitoring through the use of PDMS
provides significantly more information
about the power distributions present in the
core than is currently available. This results
in more time (i.e., earlier determination of an
adverse condition developing) for operation
action prior to having an adverse condition
develop that could lead to an accident
condition or to unfavorable initial conditions
for an accident.
Therefore, the proposed change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
2. Do[es] the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
Response: No.
Other than use of the PDMS to monitor
core power distribution, implementation of
the PDMS and associated Technical
Specification changes has no impact on plant
operations or safety, nor does it contribute in
any way to the probability or consequences
of an accident. No safety-related equipment,
safety function, or plant operation [other than
core power distribution monitoring] will be
altered as a result of this proposed change.
The possibility for a new or different type of
accident from any accident previously
evaluated is not created since the changes
associated with [the] implementation of the
PDMS do not result in a change to the design
basis of any plant component or system
[other than to the PDMS]. The evaluation of
the effects of using the PDMS to monitor core
power distribution parameters shows that all
design standards and applicable safety
criteria limits are met. [The PDMS is to
monitor the core power distribution and is,
therefore, not an accident initiator.]
The proposed changes do not result in any
event previously deemed incredible being
made credible [by the implementation of the
PDMS]. Implementation of the PDMS will
not result in any additional adverse
condition and will not result in any increase
in the challenges to safety systems. The
cycle-specific variables required by the
PDMS are calculated using NRC-approved
methods. The Technical Specifications will
continue to require operation within the
required core operating limits, and
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Fmt 4703
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appropriate actions will continue to be
[required to be] taken when or if limits are
exceeded.
The proposed change, therefore, does not
create the possibility of a new or different
kind of accident from any previously
evaluated.
3. Do[es] the proposed change involve a
significant reduction in a margin of safety?
Response: No.
No margin of safety is adversely affected by
the implementation of the PDMS. The
margins of safety provided by [the] current
Technical Specification requirements and
limits remain unchanged, as the Technical
Specifications will continue to require
operation within the core limits that are
based on NRC-approved reload design
methodologies. [These NRC-approved reload
design methodologies are not being changed.]
Appropriate measures exist to control the
values of these cycle-specific limits, and
appropriate actions will continue to be
specified and [required to be] taken for when
limits are violated. Such actions remain
unchanged.
Therefore, the proposed change does not
involve a significant reduction in a margin of
safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: John O’Neill,
Esq., Pillsbury Winthrop Shaw Pittman
LLP, 2300 N Street, NW., Washington,
DC 20037.
NRC Branch Chief: David Terao.
Wolf Creek Nuclear Operating
Corporation, Docket No. 50–482, Wolf
Creek Generating Station, Coffey
County, Kansas
Date of amendment request: June 2,
2006.
Description of amendment request:
The amendment would revise
Surveillance Requirement 3.5.2.8 in the
Technical Specifications by replacing
the phrase ‘‘trash racks and screens’’
with the word ‘‘strainers.’’ The
amendment reflects the replacement of
the containment sump suction inlet
trash racks and screens with a complex
strainer design with significantly larger
effective area in the upcoming Refueling
Outage 15. This is in response to
Generic Letter 2004–02, ‘‘Potential
Impact of Debris Blockage on
Emergency Recirculation during Design
Basis Accidents at Pressurized-Water
Reactors,’’ dated September 13, 2004.
Basis for proposed no significant
hazards consideration determination:
As required by 10 CFR 50.91(a), the
licensee has provided its analysis of the
issue of no significant hazards
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consideration, which is presented
below:
1. Does the proposed change involve a
significant increase in the probability or
consequences of an accident previously
evaluated?
Response: No.
The consequences of accidents evaluated
in the Updated Safety Analysis Report
(USAR) [for the Wolf Creek Generating
Station] that could be affected by the
proposed change are those involving the
pressurization of containment and associated
flooding of the containment and recirculation
of this fluid within the Emergency Core
Cooling System (ECCS) or the Containment
Spray System (CSS) (e.g., Loss of Coolant
Accidents). The proposed change does not
impact the initiation or probability of
occurrence of any accident. [The
containment sump trash racks and screens,
and the sump strainers that are replacing the
trash racks and screens are not initiators of
accidents.]
Although the configurations of the existing
containment recirculation sump trash racks
and screen[s,] and the replacement sump
strainer assemblies are different, they serve
the same fundamental purpose of passively
removing debris from the sump’s suction
supply of the supported system pumps.
Removal of trash racks does not impact the
adequacy of the pump NPSH [net positive
suction head] assumed in the safety analysis.
Likewise, the change does not reduce the
reliability of any supported systems or
introduce any new system interactions. The
greatly increased surface area of the new
strainer is designed to reduce head loss [at
the containment sump] and reduce the
approach velocity at the strainer face
significantly, decreasing the risk of impact
from large debris entrained in the sump flow
stream.
Therefore, the proposed change does not
involve a significant increase in the
probability or consequences of an accident
previously evaluated.
2. Does the proposed change create the
possibility of a new or different kind of
accident from any accident previously
evaluated?
Response: No.
The containment recirculation sump
strainers are a passive system used for
accident mitigation. As such, they cannot be
accident initiators. Therefore, there is no
possibility that this change could create any
new or different kind of accident.
No new accident scenarios, transient
precursors, or limiting single failures are
introduced as a result of the proposed
change. There will be no adverse effect[s] or
challenges imposed on any safety related
system as a result of the change. Therefore,
the possibility of a new or different type of
accident is not created. [The containment
recirculation sump suction inlet trash racks
and screens are being replaced with a
complex strainer design with significantly
larger effective surface area to reduce head
loss and reduce the approach velocity at the
strainer face significantly, decreasing the risk
of impact from large debris entrained in the
sump flow stream.]
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16:25 Jul 17, 2006
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There are no changes which would cause
the malfunction of safety related equipment,
assumed to be OPERABLE in the accident
analyses, as a result of the proposed
Technical Specification change. No new
equipment performance burdens are
imposed. The possibility of a malfunction of
safety related equipment with a different
result [or consequences] is not created.
Therefore, the proposed change does not
create the possibility of a new or different
[kind of] accident from any accident
previously evaluated.
3. Does the proposed change involve a
significant reduction in a margin of safety?
Response: No.
The proposed change does not affect the
acceptance criteria for any analyzed event
nor is there a change to any Safety Analysis
Limit (SAL). There will be no effect on the
manner in which safety limits, limiting safety
system settings, or limiting conditions for
operation are determined nor will there be
any effect on those plant systems necessary
to assure the accomplishment of protection
functions. The proposed change does not
adversely affect the fuel, fuel cladding,
Reactor Coolant System, or containment
integrity. The radiological dose consequence
acceptance criteria listed in the Standard
Review Plan [for accidents] will continue to
be met.
Therefore, the proposed change does not
involve a significant reduction in a margin of
safety.
The NRC staff has reviewed the
licensee’s analysis and, based on this
review, it appears that the three
standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff
proposes to determine that the
amendment request involves no
significant hazards consideration.
Attorney for licensee: Jay Silberg, Esq.,
Pillsbury Winthrop Shaw Pittman LLP,
2300 N Street, NW., Washington, DC
20037.
NRC Branch Chief: David Terao.
Notice of Issuance of Amendments to
Facility Operating Licenses
During the period since publication of
the last biweekly notice, the
Commission has issued the following
amendments. The Commission has
determined for each of these
amendments that the application
complies with the standards and
requirements of the Atomic Energy Act
of 1954, as amended (the Act), and the
Commission’s rules and regulations.
The Commission has made appropriate
findings as required by the Act and the
Commission’s rules and regulations in
10 CFR Chapter I, which are set forth in
the license amendment.
Notice of Consideration of Issuance of
Amendment to Facility Operating
License, Proposed No Significant
Hazards Consideration Determination,
and Opportunity for A Hearing in
connection with these actions was
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Fmt 4703
Sfmt 4703
40757
published in the Federal Register as
indicated.
Unless otherwise indicated, the
Commission has determined that these
amendments satisfy the criteria for
categorical exclusion in accordance
with 10 CFR 51.22. Therefore, pursuant
to 10 CFR 51.22(b), no environmental
impact statement or environmental
assessment need be prepared for these
amendments. If the Commission has
prepared an environmental assessment
under the special circumstances
provision in 10 CFR 51.12(b) and has
made a determination based on that
assessment, it is so indicated.
For further details with respect to the
action see (1) the applications for
amendment, (2) the amendment, and (3)
the Commission’s related letter, Safety
Evaluation and/or Environmental
Assessment as indicated. All of these
items are available for public inspection
at the Commission’s Public Document
Room (PDR), located at One White Flint
North, Public File Area 01F21, 11555
Rockville Pike (first floor), Rockville,
Maryland. Publicly available records
will be accessible from the Agencywide
Documents Access and Management
Systems (ADAMS) Public Electronic
Reading Room on the Internet at the
NRC Web site, https://www.nrc.gov/
reading-rm/adams.html. If you do not
have access to ADAMS or if there are
problems in accessing the documents
located in ADAMS, contact the PDR
Reference staff at 1 (800) 397–4209,
(301) 415–4737 or by e-mail to
pdr@nrc.gov.
Dominion Nuclear Connecticut, Inc.,
Docket Nos. 50–336 and 50–423,
Millstone Power Station, Unit Nos. 2
and 3, New London County, Connecticut
Date of application for amendments:
March 9, 2005, as supplemented by
letter dated July 7, 2005.
Brief description of amendments: The
amendments revised the Millstone
Power Station, Unit Nos. 2 and 3
Technical Specifications to incorporate
wording related to the reactor coolant
system, electrical power system and
refueling operations to provide
operational flexibility during mode
changes or addition of coolant during
shutdown operations.
Date of issuance: June 28, 2006.
Effective date: As of the date of
issuance and shall be implemented
within 30 days.
Amendment Nos.: 293 and 230.
Facility Operating License Nos. DPR–
65 and NPF–49: The amendments
revised the Technical Specifications.
Date of initial notice in Federal
Register: May 24, 2005 (70 FR 29788).
The additional information provided in
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the supplemental letter dated July 7,
2005, did not expand the scope of the
application as noticed and did not
change the NRC staff’s original proposed
no significant hazards consideration
determination.
The Commission’s related evaluation
of the amendment is contained in a
Safety Evaluation dated June 28, 2006.
No significant hazards consideration
comments received: No.
wwhite on PROD1PC61 with NOTICES
Duke Energy Corporation, Docket Nos.
50–269, 50–270, and 50–287, Oconee
Nuclear Station, Units 1, 2, and 3,
Oconee County, South Carolina
Date of application of amendments:
January 5, 2005, as supplemented
November 21, 2005.
Brief description of amendments: The
amendments revised Technical
Specifications (TSs) 5.5.19.b, 5.1.19.c,
and TS Surveillance Requirement (SR)
3.8.1.9 associated with the Lee
Combustion Turbine (LCT) testing
program. TS 5.5.19 required verification
that an LCT can supply the equivalent
of one unit’s maximum safeguards
loads, plus two units’ Mode 3 loads
when connected to the system grid
every 12 months. The amendments
clarified this requirement as ‘‘Verify an
LCT can supply equivalent of one unit’s
Loss of Coolant Accident (LOCA) loads
plus two units’ Loss of Offsite Power
(LOOP) loads when connected to system
grid every 12 months.’’ TS 5.5.19.c and
SR 3.8.1.9 were revised for consistency.
Date of Issuance: July 5, 2006.
Effective date: As of the date of
issuance and shall be implemented
within 30 days from the date of
issuance.
Amendment Nos.: 352/354/353.
Renewed Facility Operating License
Nos. DPR–38, DPR–47, and DPR–55:
Amendments revised the Operating
Licenses and Technical Specifications.
Date of initial notice in Federal
Register: February 15, 2005 (70 FR
7764). The additional information
provided in the supplemental letter
dated November 21, 2005, did not
expand the scope of the application as
noticed and did not change the NRC
staff’s original proposed no significant
hazards consideration determination.
The Commission’s related evaluation
of the amendments is contained in a
Safety Evaluation dated July 5, 2006.
No significant hazards consideration
comments received: No.
Nine Mile Point Nuclear Station, LLC,
Docket No. 50–410, Nine Mile Point
Nuclear Station, Unit 2, Oswego County,
New York
Date of application for amendment:
December 29, 2005.
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16:25 Jul 17, 2006
Jkt 208001
Brief description of amendment: The
amendment deleted License Condition,
Section 2.F, that requires the reporting
of violations in Section 2.C of the
Facility Operating License.
Date of issuance: June 28, 2006.
Effective date: As of the date of
issuance to be implemented within 60
days.
Amendment No.: 116.
Facility Operating License No. NPF–
69: Amendment revised the Facility
Operating License.
Date of initial notice in Federal
Register: April 25, 2006 (71 FR 23958).
The Commission’s related evaluation
of the amendment is contained in a
Safety Evaluation dated June 28, 2006.
No significant hazards consideration
comments received: No.
Southern Nuclear Operating Company,
Inc., Georgia Power Company,
Oglethorpe Power Corporation,
Municipal Electric Authority of Georgia,
City of Dalton, Georgia, Docket Nos. 50–
321 and 50–366, Edwin I. Hatch Nuclear
Plant, Unit Nos. 1 and 2, Appling
County, Georgia
Date of application for amendments:
February 17, 2006.
Brief description of amendments: The
amendments revised the Technical
Specifications (TSs) adding Limiting
Condition for Operation (LCO) 3.0.8 to
allow a delay time for entering a
supported system TS when the
inoperability is due solely to an
inoperable snubber, if risk is assessed
and managed consistent with the
program in place for complying with the
requirements of 10 CFR 50.65(a)(4).
Date of issuance: June 29, 2006.
Effective date: As of the date of
issuance and shall be implemented
within 90 days from the date of
issuance.
Amendment Nos.: 250/194.
Renewed Facility Operating License
Nos. DPR–57 and NPF–5: Amendments
revised the licenses and the technical
specifications.
Date of initial notice in Federal
Register: April 25, 2006 (71 FR 23960).
The Commission’s related evaluation
of the amendments is contained in a
Safety Evaluation dated June 29, 2006.
No significant hazards consideration
comments received: No.
Southern Nuclear Operating Company,
Inc., Docket Nos. 50–424 and 50–425,
Vogtle Electric Generating Plant, Unit
Nos. 1 and 2, Burke County, Georgia
Date of application for amendments:
February 17, 2006.
Brief description of amendments: The
amendments revised the Technical
Specifications (TSs) adding Limiting
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Fmt 4703
Sfmt 4703
Condition for Operation (LCO) 3.0.8 and
renumbering existing LCO 3.0.8 to LCO
3.0.9 to allow a delay time for entering
a supported system TS when the
inoperability is due solely to an
inoperable snubber, if risk is assessed
and managed consistent with the
program in place for complying with the
requirements of 10 CFR 50.65(a)(4).
Date of issuance: June 29, 2006.
Effective date: As of the date of
issuance and shall be implemented
within 90 days from the date of
issuance.
Amendment Nos.: 141/121.
Facility Operating License Nos. NPF–
68 and NPF–81: Amendments revised
the Licenses and the Technical
Specifications.
Date of initial notice in Federal
Register: April 25, 2006 (71 FR 23960).
The Commission’s related evaluation
of the amendments is contained in a
Safety Evaluation dated June 29, 2006.
No significant hazards consideration
comments received: No.
Tennessee Valley Authority, Docket
Nos. 50–327 and 50–328, Sequoyah
Nuclear Plant, Units 1 and 2, Hamilton
County, Tennessee
Date of application for amendments:
December 19, 2005, as supplemented by
letter dated March 30, 2006.
Brief description of amendments: The
amendments modified several parts of
Technical Specification Surveillance
Requirement (SR) 4.0.5, both to change
the surveillance intervals for which the
25 percent extension provided in SR
3.0.2 would apply, and to replace the
references in SR 4.0.5 to the American
Society of Mechanical Engineers
(ASME) Boiler and Pressure Vessel
Code, Section XI, with the ASME
Operation and Maintenance Code.
Date of issuance: June 16, 2006.
Effective date: As of the date of
issuance and shall be implemented
within 45 days.
Amendment Nos.: 308 and 297.
Facility Operating License Nos. DPR–
77 and DPR–79: Amendments revised
the technical specifications.
Date of initial notice in Federal
Register: February 14, 2006 (71 FR
7183).
The supplemental letter dated March
30, 2006, provided clarifying
information that did not change the
initial proposed no significant hazards
consideration determination.
The Commission’s related evaluation
of the amendments is contained in a
Safety Evaluation dated June 16, 2006.
No significant hazards consideration
comments received: No.
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Federal Register / Vol. 71, No. 137 / Tuesday, July 18, 2006 / Notices
Virginia Electric and Power Company, et
al., Docket Nos. 50–280 and 50–281,
Surry Power Station, Unit Nos. 1 and 2,
Surry County, Virginia
Date of application for amendments:
April 20, 2006, as supplemented on May
15, 2006.
Brief description of amendments:
These amendments revised the reactor
coolant pressure and temperature limits,
low-temperature overpressure
protection system (LTOPS) setpoint
values, and LTOPS enable temperatures
for up to 28.8 effective full-power years
(EFPYs) and 29.4 EFPYs of operation at
Surry Power Station, Unit Nos. 1 and 2,
respectively.
Date of issuance: June 29, 2006.
Effective date: As of the date of
issuance.
Amendment Nos.: 248/247.
Renewed Facility Operating License
Nos. DPR–32 and DPR–37: Amendments
revised the License and the Technical
Specifications.
Date of initial notice in Federal
Register: April 28, 2006 (71 FR 25249).
The May 15, 2006, supplement
contained clarifying information only
and did not change the initial proposed
no significant hazards consideration
determination or expand the scope of
the initial application.
The Commission’s related evaluation
of the amendments is contained in a
Safety Evaluation dated June 29, 2006.
No significant hazards consideration
comments received: No.
Dated at Rockville, Maryland, this 11th day
of July.
For the Nuclear Regulatory Commission.
Catherine Haney,
Director, Division of Operating Reactor
Licensing, Office of Nuclear Reactor
Regulation.
[FR Doc. 06–6246 Filed 7–17–06; 8:45 am]
BILLING CODE 7590–01–P
SECURITIES AND EXCHANGE
COMMISSION
Sunshine Act Meeting
FEDERAL REGISTER CITATION OF PREVIOUS
ANNOUNCEMENT: [71 FR 40174, July 14,
Closed meeting.
PLACE: 100 F Street, NE., Washington,
DC.
DATE AND TIME OF PREVIOUSLY ANNOUNCED
MEETING: Tuesday, July 18, 2006 at 10
wwhite on PROD1PC61 with NOTICES
Dated: July 14, 2006.
J. Lynn Taylor,
Assistant Secretary.
[FR Doc. 06–6303 Filed 7–14–06; 10:52 am]
BILLING CODE 8010–01–P
SECURITIES AND EXCHANGE
COMMISSION
[Release No. 34–54136; File No. 4–517]
Program for Allocation of Regulatory
Responsibilities Pursuant to Rule 17d–
2; Order Granting Approval of Plan for
Allocation of Regulatory
Responsibilities Between The
NASDAQ Stock Market LLC and the
National Association of Securities
Dealers, Inc.
July 12, 2006.
Notice is hereby given that the
Securities and Exchange Commission
(‘‘SEC’’ or ‘‘Commission’’) has issued an
Order, pursuant to Sections 17(d) 1 and
11A(a)(3)(B) 2 of the Securities Exchange
of 1934 (‘‘Act’’), granting approval and
declaring effective a plan for allocating
regulatory responsibility filed pursuant
to Rule 17d–2 of the Act,3 by The
NASDAQ Stock Market LLC (‘‘Nasdaq’’)
and the National Association of
Securities Dealers, Inc. (‘‘NASD’’).
Accordingly, NASD shall assume, in
addition to the regulatory responsibility
it has under the Act, the regulatory
responsibilities allocated to it under the
plan. At the same time, Nasdaq is
relieved of those regulatory
responsibilities allocated to NASD.4
I. Introduction
Section 19(g)(1) of the Act,5 among
other things, requires every national
securities exchange and registered
securities association (‘‘SRO’’) to
examine for, and enforce compliance by,
its members and persons associated
a.m.
Time change.
The closed meeting scheduled for
Tuesday, July 18, 2006 at 10 a.m. has
been changed to Tuesday, July 18, 2006
at 11 a.m.
CHANGE IN THE MEETING:
16:25 Jul 17, 2006
Jkt 208001
U.S.C. 78q(d).
U.S.C. 78k–1(a)(3)(B).
3 17 CFR 240.17d–2.
4 On January 13, 2006, the Commission approved
Nasdaq’s application for registration as a national
securities exchange. The Commission conditioned
the operation of the Nasdaq Exchange upon
satisfaction of several requirements, one of which
was the approval by the Commission of an
agreement pursuant to Rule 17d–2 between Nasdaq
and NASD. Securities Exchange Act Release No.
53128, 71 FR 3550 (January 23, 2006). Commission
approval of this plan allocating regulatory
responsibility satisfies this requirement.
5 15 U.S.C. 78s(g)(1).
with its members with the Act, the rules
and regulations thereunder, and the
SRO’s own rules, unless the SRO is
relieved of this responsibility pursuant
to Section 17(d) or 19(g)(2) of the Act.6
Section 17(d)(1) of the Act was
intended, in part, to eliminate
unnecessary multiple examinations and
regulatory duplication for those brokerdealers that maintain memberships in
more than one SRO.7 With respect to
common members of two or more SROs,
Section 17(d)(1) authorizes the
Commission, by rule or order, to relieve
an SRO of the responsibility to receive
regulatory reports, to examine for and
enforce compliance with applicable
statutes, rules and regulations, or to
perform other specified regulatory
functions.
To implement Section 17(d)(1), the
Commission adopted two rules: Rule
17d–18 and Rule 17d–2 under the Act.9
Rule 17d–2 under the Act permits SROs
to propose joint plans allocating
regulatory responsibilities, other than
financial responsibility rules, with
respect to common members. Under
paragraph (c) of Rule 17d–2, the
Commission may declare such a plan
effective if, after providing for notice
and comment, it determines that the
plan is necessary or appropriate in the
public interest and for the protection of
investors, to foster cooperation and
coordination among self-regulatory
organizations, to remove impediments
to and foster the development of a
national market system and a national
clearance and settlement system, and in
conformity with the factors set forth in
Section 17(d) of the Act. Upon
effectiveness of a plan filed pursuant to
Rule 17d–2, any self-regulatory
organization is relieved of those
regulatory responsibilities for common
members that are allocated by the plan
to another self-regulatory organization.
On April 17, 2006, the Commission
published notice of the filing by Nasdaq
and NASD of a joint plan allocating
regulatory responsibility for common
members.10 No comments were
received. On July 12, 2006, Nasdaq and
NASD filed an amended joint plan for
1 15
2006].
STATUS:
VerDate Aug<31>2005
At times, changes in Commission
priorities require alterations in the
scheduling of meeting items. For further
information and to ascertain what, if
any, matters have been added, deleted
or postponed, please contact the Office
of the Secretary at (202) 551–5400.
40759
PO 00000
2 15
Frm 00074
Fmt 4703
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6 15
U.S.C. 78q(d) and 15 U.S.C. 78s(g)(2).
Acts Amendments of 1975, Report of
the Senate Committee on Banking, Housing, and
Urban Affairs to Accompany S. 249, S. Rep. No. 94–
75, 94th Cong., 1st Session. 32 (1975).
8 17 CFR 240.17d–1. Rule 17d–1 authorizes the
Commission to designate a single SRO as the
designated examining authority (‘‘DEA’’) to
examine common members for compliance with
financial responsibility requirements imposed by
the Act, the rules thereunder, and SRO rules.
9 17 CFR 240.17d–2.
10 Securities Exchange Act Release No. 53628
(April 10, 2006), 71 FR 19763.
7 Securities
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Agencies
[Federal Register Volume 71, Number 137 (Tuesday, July 18, 2006)]
[Notices]
[Pages 40742-40759]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 06-6246]
-----------------------------------------------------------------------
NUCLEAR REGULATORY COMMISSION
Biweekly Notice; Applications and Amendments to Facility
Operating Licenses Involving No Significant Hazards Considerations
I. Background
Pursuant to section 189a.(2) of the Atomic Energy Act of 1954, as
amended (the Act), the U.S. Nuclear Regulatory Commission (the
Commission or NRC staff) is publishing this regular biweekly notice.
The Act requires the Commission publish notice of any amendments
issued, or proposed to be issued and grants the Commission the
authority to issue and make immediately effective any amendment to an
operating license upon a determination by the Commission that such
amendment involves no significant hazards consideration,
notwithstanding
[[Page 40743]]
the pendency before the Commission of a request for a hearing from any
person.
This biweekly notice includes all notices of amendments issued, or
proposed to be issued from June 23, 2006 to July 6, 2006. The last
biweekly notice was published on July 5, 2006 (71 FR 38180).
Notice of Consideration of Issuance of Amendments to Facility Operating
Licenses, Proposed No Significant Hazards Consideration Determination,
and Opportunity for a Hearing
The Commission has made a proposed determination that the following
amendment requests involve no significant hazards consideration. Under
the Commission's regulations in 10 CFR 50.92, this means that operation
of the facility in accordance with the proposed amendment would not (1)
involve a significant increase in the probability or consequences of an
accident previously evaluated; or (2) create the possibility of a new
or different kind of accident from any accident previously evaluated;
or (3) involve a significant reduction in a margin of safety. The basis
for this proposed determination for each amendment request is shown
below.
The Commission is seeking public comments on this proposed
determination. Any comments received within 30 days after the date of
publication of this notice will be considered in making any final
determination. Within 60 days after the date of publication of this
notice, the licensee may file a request for a hearing with respect to
issuance of the amendment to the subject facility operating license and
any person whose interest may be affected by this proceeding and who
wishes to participate as a party in the proceeding must file a written
request for a hearing and a petition for leave to intervene.
Normally, the Commission will not issue the amendment until the
expiration of 60 days after the date of publication of this notice. The
Commission may issue the license amendment before expiration of the 60-
day period provided that its final determination is that the amendment
involves no significant hazards consideration. In addition, the
Commission may issue the amendment prior to the expiration of the 30-
day comment period should circumstances change during the 30-day
comment period such that failure to act in a timely way would result,
for example in derating or shutdown of the facility. Should the
Commission take action prior to the expiration of either the comment
period or the notice period, it will publish in the Federal Register a
notice of issuance. Should the Commission make a final No Significant
Hazards Consideration Determination, any hearing will take place after
issuance. The Commission expects that the need to take this action will
occur very infrequently.
Written comments may be submitted by mail to the Chief, Rules and
Directives Branch, Division of Administrative Services, Office of
Administration, U.S. Nuclear Regulatory Commission, Washington, DC
20555-0001, and should cite the publication date and page number of
this Federal Register notice. Written comments may also be delivered to
Room 6D22, Two White Flint North, 11545 Rockville Pike, Rockville,
Maryland, from 7:30 a.m. to 4:15 p.m. Federal workdays. Copies of
written comments received may be examined at the Commission's Public
Document Room (PDR), located at One White Flint North, Public File Area
O1F21, 11555 Rockville Pike (first floor), Rockville, Maryland. The
filing of requests for a hearing and petitions for leave to intervene
is discussed below.
Within 60 days after the date of publication of this notice, the
licensee may file a request for a hearing with respect to issuance of
the amendment to the subject facility operating license and any person
whose interest may be affected by this proceeding and who wishes to
participate as a party in the proceeding must file a written request
for a hearing and a petition for leave to intervene. Requests for a
hearing and a petition for leave to intervene shall be filed in
accordance with the Commission's ``Rules of Practice for Domestic
Licensing Proceedings'' in 10 CFR part 2. Interested persons should
consult a current copy of 10 CFR 2.309, which is available at the
Commission's PDR, located at One White Flint North, Public File Area
01F21, 11555 Rockville Pike (first floor), Rockville, Maryland.
Publicly available records will be accessible from the Agencywide
Documents Access and Management System's (ADAMS) Public Electronic
Reading Room on the Internet at the NRC Web site, https://www.nrc.gov/
reading-rm/doc-collections/cfr/. If a request for a hearing or petition
for leave to intervene is filed within 60 days, the Commission or a
presiding officer designated by the Commission or by the Chief
Administrative Judge of the Atomic Safety and Licensing Board Panel,
will rule on the request and/or petition; and the Secretary or the
Chief Administrative Judge of the Atomic Safety and Licensing Board
will issue a notice of a hearing or an appropriate order.
As required by 10 CFR 2.309, a petition for leave to intervene
shall set forth with particularity the interest of the petitioner in
the proceeding, and how that interest may be affected by the results of
the proceeding. The petition should specifically explain the reasons
why intervention should be permitted with particular reference to the
following general requirements: (1) The name, address, and telephone
number of the requestor or petitioner; (2) the nature of the
requestor's/petitioner's right under the Act to be made a party to the
proceeding; (3) the nature and extent of the requestor's/petitioner's
property, financial, or other interest in the proceeding; and (4) the
possible effect of any decision or order which may be entered in the
proceeding on the requestor's/petitioner's interest. The petition must
also set forth the specific contentions which the petitioner/requestor
seeks to have litigated at the proceeding.
Each contention must consist of a specific statement of the issue
of law or fact to be raised or controverted. In addition, the
petitioner/requestor shall provide a brief explanation of the bases for
the contention and a concise statement of the alleged facts or expert
opinion which support the contention and on which the petitioner/
requestor intends to rely in proving the contention at the hearing. The
petitioner/requestor must also provide references to those specific
sources and documents of which the petitioner is aware and on which the
petitioner/requestor intends to rely to establish those facts or expert
opinion. The petition must include sufficient information to show that
a genuine dispute exists with the applicant on a material issue of law
or fact. Contentions shall be limited to matters within the scope of
the amendment under consideration. The contention must be one which, if
proven, would entitle the petitioner/requestor to relief. A petitioner/
requestor who fails to satisfy these requirements with respect to at
least one contention will not be permitted to participate as a party.
Those permitted to intervene become parties to the proceeding,
subject to any limitations in the order granting leave to intervene,
and have the opportunity to participate fully in the conduct of the
hearing.
If a hearing is requested, and the Commission has not made a final
determination on the issue of no significant hazards consideration, the
Commission will make a final determination on the issue of no
significant hazards consideration. The final determination will serve
to decide
[[Page 40744]]
when the hearing is held. If the final determination is that the
amendment request involves no significant hazards consideration, the
Commission may issue the amendment and make it immediately effective,
notwithstanding the request for a hearing. Any hearing held would take
place after issuance of the amendment. If the final determination is
that the amendment request involves a significant hazards
consideration, any hearing held would take place before the issuance of
any amendment.
A request for a hearing or a petition for leave to intervene must
be filed by: (1) First class mail addressed to the Office of the
Secretary of the Commission, U.S. Nuclear Regulatory Commission,
Washington, DC 20555-0001, Attention: Rulemaking and Adjudications
Staff; (2) courier, express mail, and expedited delivery services:
Office of the Secretary, Sixteenth Floor, One White Flint North, 11555
Rockville Pike, Rockville, Maryland 20852, Attention: Rulemaking and
Adjudications Staff; (3) E-mail addressed to the Office of the
Secretary, U.S. Nuclear Regulatory Commission, HearingDocket@nrc.gov;
or (4) facsimile transmission addressed to the Office of the Secretary,
U.S. Nuclear Regulatory Commission, Washington, DC, Attention:
Rulemakings and Adjudications Staff at (301) 415-1101, verification
number is (301) 415-1966. A copy of the request for hearing and
petition for leave to intervene should also be sent to the Office of
the General Counsel, U.S. Nuclear Regulatory Commission, Washington, DC
20555-0001, and it is requested that copies be transmitted either by
means of facsimile transmission to (301) 415-3725 or by e-mail to
OGCMailCenter@nrc.gov. A copy of the request for hearing and petition
for leave to intervene should also be sent to the attorney for the
licensee.
Nontimely requests and/or petitions and contentions will not be
entertained absent a determination by the Commission or the presiding
officer of the Atomic Safety and Licensing Board that the petition,
request and/or the contentions should be granted based on a balancing
of the factors specified in 10 CFR 2.309(a)(1)(i)-(viii).
For further details with respect to this action, see the
application for amendment which is available for public inspection at
the Commission's PDR, located at One White Flint North, Public File
Area 01F21, 11555 Rockville Pike (first floor), Rockville, Maryland.
Publicly available records will be accessible from the ADAMS Public
Electronic Reading Room on the Internet at the NRC Web site, https://
www.nrc.gov/reading-rm/adams.html. If you do not have access to ADAMS
or if there are problems in accessing the documents located in ADAMS,
contact the PDR Reference staff at 1 (800) 397-4209, (301) 415-4737 or
by e-mail to pdr@nrc.gov.
AmerGen Energy Company, LLC, Docket No. 50-289, Three Mile Island
Nuclear Station, Unit 1 (TMI-1), Dauphin County, Pennsylvania
Date of amendment request: May 15, 2006.
Description of amendment request: The amendment would revise the
Technical Specification (TS) requirements related to steam generator
tube integrity. The proposed changes are generally consistent with
Revision 4 to Technical Specification Task Force (TSTF) Standard
Technical Specification Change Traveler, TSTF-449, ``Steam Generator
Tube Integrity.'' The availability of this TS improvement was announced
in the Federal Register, on May 6, 2005 (70 FR 24126) as part of the
consolidated line item improvement process (CLIIP). The proposed
amendment includes changes to licensing pages to delete License
Condition 2.c.(8), ``Repaired Steam Generators;'' changes to TS 3.1.6,
``LEAKAGE;'' changes to TS Section 3.1.1.2, ``Steam Generators and
Steam Generator (SG) Tube Integrity;'' revising TS Section 4.19,
``Steam Generator (SG) Tube Integrity;'' adding new TS 6.9.6, ``Steam
Generator Tube Inspection Report;'' and adding new TS 6.19, ``Steam
Generator (SG) Program.''
Basis for proposed no significant hazards consideration
determination (NSHC): The NRC staff published a notice of opportunity
for comment in the Federal Register on March 2, 2005 (70 FR 10298), on
possible amendments adopting TSTF-449, including a model safety
evaluation and model NSHC determination, using the CLIIP. The NRC staff
subsequently issued a notice of availability of the models for
referencing in license amendment applications in the Federal Register
on May 6, 2005 (70 FR 24126). The licensee affirmed the applicability
of the following NSHC determination in its application dated May 15,
2006. As required by 10 CFR 50.91(a), an analysis of the issue of no
significant hazards consideration is presented below:
Criterion 1--The Proposed Change Does Not Involve a Significant
Increase in the Probability or Consequences of an Accident
Previously Evaluated.
The proposed change requires a SG Program that includes
performance criteria that will provide reasonable assurance that the
SG tubing will retain integrity over the full range of operating
conditions (including startup, operation in the power range, hot
standby, cooldown and all anticipated transients included in the
design specification). The SG performance criteria are based on tube
structural integrity, accident induced leakage, and operational
LEAKAGE.
A Steam Generator Tube Rupture (SGTR) event is one of the
design-basis accidents that are analyzed as part of a plant's
licensing basis. In the analysis of a SGTR event, a bounding primary
to secondary LEAKAGE rate equal to the operational LEAKAGE rate
limits in the licensing basis plus the LEAKAGE rate associated with
a double-ended rupture of a single tube is assumed.
For other design-basis accidents such as Main Steam Line Break
(MSLB), rod ejection, and reactor coolant pump locked rotor the
tubes are assumed to retain their structural integrity (i.e., they
are assumed not to rupture). These analyses typically assume that
primary to secondary LEAKAGE for all SGs is 1 gallon per minute or
increases to 1 gallon per minute as a result of accident-induced
stresses. The accident-induced leakage criterion introduced by the
proposed changes accounts for tubes that may leak during design-
basis accidents. The accident-induced leakage criterion limits this
leakage to no more than the value assumed in the accident analysis.
The SG performance criteria proposed change to the TSs
identifies the standards against which tube integrity is to be
measured. Meeting the performance criteria provides reasonable
assurance that the SG tubing will remain capable of fulfilling its
specific safety function of maintaining reactor coolant pressure
boundary integrity throughout each operating cycle and in the
unlikely event of a design-basis accident. The performance criteria
are only a part of the SG Program required by the proposed change to
the TSs. The program, defined by NEI [Nuclear Energy Institute] 97-
06, ``Steam Generator Program Guidelines,'' includes a framework
that incorporates a balance of prevention, inspection, evaluation,
repair, and leakage monitoring. The proposed changes do not,
therefore, significantly increase the probability of an accident
previously evaluated.
The consequences of design-basis accidents are, in part,
functions of the DOSE EQUIVALENT I-131 in the primary coolant and
the primary to secondary LEAKAGE rates resulting from an accident.
Therefore, limits are included in the plant technical specifications
for operational leakage and for DOSE EQUIVALENT I-131 in primary
coolant to ensure the plant is operated within its analyzed
condition. The typical analysis of the limiting design-basis
accident assumes that the primary-to-secondary leak rate after the
accident is 1 gallon per minute with no more than 500 gallons per
day in any one SG, and that the reactor coolant activity levels of
DOSE EQUIVALENT I-131 are at the TS values before the accident.
The proposed change does not affect the design of the SGs, their
method of operation, or primary coolant chemistry controls. The
proposed approach updates the current TSs and enhances the
requirements for SG
[[Page 40745]]
inspections. The proposed change does not adversely impact any other
previously-evaluated design-basis accident and is an improvement
over the current TSs.
Therefore, the proposed change does not affect the consequences
of a SGTR accident and the probability of such an accident is
reduced. In addition, the proposed change does not affect the
consequences of an MSLB, rod ejection, or a reactor coolant pump
locked rotor event, or other previously-evaluated accident.
Criterion 2--The Proposed Change Does Not Create the Possibility
of a New or Different Kind of Accident From Any Previously
Evaluated.
The proposed performance-based requirements are an improvement
over the requirements imposed by the current technical
specifications. Implementation of the proposed SG Program will not
introduce any adverse changes to the plant design-basis or
postulated accidents resulting from potential tube degradation. The
result of the implementation of the SG Program will be an
enhancement of SG tube performance. Primary to secondary LEAKAGE
that may be experienced during all plant conditions will be
monitored to ensure it remains within current accident analysis
assumptions.
The proposed change does not affect the design of the SGs, their
method of operation, or primary or secondary coolant chemistry
controls. In addition, the proposed change does not impact any other
plant system or component. The change enhances SG inspection
requirements.
Therefore, the proposed change does not create the possibility
of a new or different type of accident from any accident previously
evaluated.
Criterion 3--The Proposed Change Does Not Involve a Significant
Reduction in the Margin of Safety.
The SG tubes in pressurized-water reactors are an integral part
of the reactor coolant pressure boundary and, as such, are relied
upon to maintain the primary system's pressure and inventory. As
part of the reactor coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as a heat transfer surface
between the primary and secondary systems such that residual heat
can be removed from the primary system. In addition, the SG tubes
isolate the radioactive fission products in the primary coolant from
the secondary system. In summary, the safety function of an SG is
maintained by ensuring the integrity of its tubes.
Steam generator tube integrity is a function of the design,
environment, and the physical condition of the tube. The proposed
change does not affect tube design or operating environment. The
proposed change is expected to result in an improvement in the tube
integrity by implementing the SG Program to manage SG tube
inspection, assessment, repair, and plugging. The requirements
established by the SG Program are consistent with those in the
applicable design codes and standards and are an improvement over
the requirements in the current TSs.
For the above reasons, the margin of safety is not changed and
overall plant safety will be enhanced by the proposed change to the
TSs.
The NRC staff proposes to determine that the amendment request
involves no significant hazards consideration.
Attorney for licensee: Mr. Brad Fewell, Assistant General Counsel,
Exelon Generation Company, LLC, 200 Exelon Way, Kennett Square, PA
19348.
NRC Branch Chief: Darrell J. Roberts.
Duke Power Company LLC, Docket Nos. 50-269, 50-270, and 50-287, Oconee
Nuclear Station, Units 1, 2, and 3, Oconee County, South Carolina
Date of amendment request: June 1, 2006.
Description of amendment request: The proposed amendments would
revise the Updated Final Safety Analysis Report (UFSAR) to incorporate
the use of a fiber-reinforced polymer (FRP) system to strengthen
existing masonry walls against tornado effects.
Basis for proposed no significant hazards consideration
determination: As required by 10 CFR 50.91(a), the licensee has
provided its analysis of the issue of no significant hazards
consideration, which is presented below:
1. Involve a significant increase in the probability or
consequences of an accident previously evaluated.
Response: Physical protection from a tornado event is a design
basis criterion rather than a requirement of a previously analyzed
UFSAR accident analysis.
The current licensing basis (CLB) for Oconee states that
systems, structures, and components (SSC's) required to shut down
and maintain the units in a shutdown condition will not fail as a
result of damage caused by natural phenomena.
The in-fill masonry walls to be strengthened using an FRP system
are passive, non-structural elements. The use of an FRP system on
existing Auxiliary Building masonry walls will allow them to resist
uniform pressure loads resulting from a tornado and will not
adversely affect the structure's ability to withstand other design
basis events such as earthquakes or fires. Therefore, the proposed
use of FRP on existing masonry walls will not significantly increase
the probability or consequences of an accident previously evaluated.
2. Create the possibility of a new or different kind of accident
from any accident previously evaluated.
Response: The final state of the FRP system is passive in nature
and will not initiate or cause an accident. More generally, this
understanding supports the conclusion that the potential for new or
different kinds of accidents is not created.
3. Involve a significant reduction in a margin of safety.
Response: The application of an FRP system to existing auxiliary
building masonry walls will either act to restore the margin of
safety described in the UFSAR, e.g., the Unit 3 Control Room north
wall, or enhance the margin of safety, e.g., the West Penetration
Room walls, by increasing the walls' ability to resist tornado-
induced differential pressure and/or tornado wind. Consequently,
this change does not involve a significant reduction in a margin of
safety.
The NRC staff has reviewed the licensee's analysis and, based on
this review, it appears that the three standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff proposes to determine that the
amendment request involves no significant hazards consideration.
Attorney for licensee: Ms. Lisa F. Vaughn, Legal Department
(PB05E), Duke Energy Corporation, 422 South Church Street, Charlotte,
North Carolina 28201-1006.
NRC Branch Chief: Evangelos C. Marinos.
Energy Northwest, Docket No. 50-397, Columbia Generating Station,
Benton County, Washington
Date of amendment request: May 22, 2006.
Description of amendment request: The proposed license amendment
request would revise: (1) Surveillance Requirement (SR) 3.8.1.11 to
remove the MODE restriction from Note 2 for Diesel Generator (DG)-3
only, (2) SR 3.8.1.12 to remove the MODE restriction from Note 2 for
DG-3 only, (3) SR 3.8.1.16 to remove the MODE restriction from the Note
for DG-3 only, and (4) Revise SR 3.8.1.19 to remove the MODE
restriction from Note 2 for DG-3 only.
Basis for proposed no significant hazards consideration
determination: As required by 10 CFR 50.91(a), the licensee has
provided its analysis of the issue of no significant hazards
consideration, which is presented below:
1. Does the operation of Columbia Generating Station in
accordance with the proposed amendment involve a significant
increase in the probability or consequences of an accident
previously evaluated?
Response: No.
The DG and its associated emergency loads are accident
mitigating features, not accident initiating equipment. Therefore,
there will be no impact on any accident probabilities by the
approval of the requested amendment. The design of plant equipment
is not being modified by these proposed changes. The capability of
DG-1 and DG-2 to supply power to their safety related buses as
designed will not be compromised by permitting performance of DG-3
testing during power operations. Columbia's Technical Specifications
require the RCIC [reactor core isolation cooling] system to be
operable whenever this testing is performed at power. This ensures
that the high-pressure injection function is maintained during the
time the HPCS injection valve is disabled
[[Page 40746]]
during testing. In the event of a design basis accident during
testing, the HPCS [high-pressure core spray] system could be
returned to service well within the 14-day outage time allowed by
Technical Specifications. Additionally, the ability of the Standby
Liquid Coolant (SLC) system to perform its design safety function
would not be affected because SLC is connected downstream of the
HPCS injection valve. Therefore, there would be no significant
impact on any accident consequences.
Based on the above, the proposed change to permit certain DG
surveillance tests to be performed during plant operation will have
no effect on accident probabilities or consequences. Therefore, the
proposed change does not involve a significant Increase in the
probability or consequences of an accident previously evaluated.
2. Does the operation of Columbia Generating Station in
accordance with the proposed amendment create the possibility of a
new or different kind of accident from any accident previously
evaluated?
Response: No.
No new accident causal mechanisms would be introduced as a
result of NRC approval of this amendment request since no changes
are being made to the plant that would introduce any new accident
causal mechanisms. Equipment will be operated in the same
configuration with the exception of the plant mode in which the
testing is conducted. This amendment request does not impact any
plant systems that are accident initiators; neither does it
adversely impact any accident mitigating systems.
Based on the above, implementation of the proposed changes would
not create the possibility of a new or different kind of accident
from any accident previously evaluated.
3. Does the operation of Columbia Generating Station in
accordance with the proposed amendment involve a significant
reduction in the margin of safety?
Response: No.
Margin of safety is related to the confidence in the ability of
the fission product barriers to perform their design functions
during and following an accident situation. These barriers include
the fuel cladding, the reactor coolant system, and the containment
system. The proposed changes to the testing requirements for the DG
do not affect the operability requirements for the DG, as
verification of such operability will continue to be performed as
required. Continued verification of operability supports the
capability of the DG to perform its required function of providing
emergency power to plant equipment that supports or constitutes the
fission product barriers. Consequently, the performance of these
fission product barriers will not be impacted by implementation of
this proposed amendment. In addition, the proposed changes involve
no changes to setpoints or limits established or assumed by the
accident analysis. On this, and the above basis, no safety margins
will be impacted.
Energy Northwest concludes that there is no significant
reduction in the margin of safety.
The NRC staff has reviewed the licensee's analysis and, based on
this review, it appears that the three standards of 10 CFR 50.92(c) are
satisfied. Therefore, the NRC staff proposes to determine that the
amendment request involves no significant hazards consideration.
Attorney for licensee: William A. Horin, Esq., Winston & Strawn,
1700 K Street, NW., Washington, DC 20006-3817.
NRC Branch Chief: David Terao.
Florida Power and Light Company, Docket No. 50-335, St. Lucie Plant,
Unit No. 1, St. Lucie County, Florida
Date of amendment request: April 24, 2006.
Description of amendment request: The proposed amendment would
revise the Technical Specifications (TSs) consistent with the NRC-
approved Revision 4 to TS Task Force (TSTF) Standard TS Change
Traveler, TSTF-449, ``Steam Generator Tube Integrity.''
The NRC staff issued a notice of opportunity for comment in the
Federal Register on March 2, 2005 (70 FR 10298), on possible amendments
adopting TSTF-449, including a model safety evaluation and model no
significant hazards consideration (NSHC) determination, using the
consolidated line item improvement process. The NRC staff subsequently
issued a notice of availability of the models for referencing in
license amendment applications in the Federal Register on May 6, 2005
(70 FR 24126). The licensee affirmed the applicability of the following
NSHC determination in its application dated April 24, 2006. Basis for
proposed no significant hazards consideration determination: As
required by 10 CFR 50.91(a), an analysis of the issue of no significant
hazards consideration is presented below:
Criterion 1--The proposed change does not involve a significant
increase in the probability or consequences of an accident
previously evaluated.
The proposed change requires a SG [Steam Generator] Program that
includes performance criteria that will provide reasonable assurance
that the SG tubing will retain integrity over the full range of
operating conditions (including startup, operation in the power
range, hot standby, cooldown and all anticipated transients included
in the design specification). The SG performance criteria are based
on tube structural integrity, accident induced leakage, and
operational LEAKAGE.
A[n] SGTR [steam generator tube rupture] event is one of the
design basis accidents that are analyzed as part of a plant's
licensing basis. In the analysis of a[n] SGTR event, a bounding
primary to secondary LEAKAGE rate equal to the operational LEAKAGE
rate limits in the licensing basis plus the LEAKAGE rate associated
with a double-ended rupture of a single tube is assumed.
For other design basis accidents such as MSLB [main steamline
break], rod ejection, and reactor coolant pump locked rotor the
tubes are assumed to retain their structural integrity (i.e., they
are assumed not to rupture). These analyses typically assume that
primary to secondary LEAKAGE for all SGs is 1 gallon per minute or
increases to 1 gallon per minute as a result of accident induced
stresses. The accident induced leakage criterion introduced by the
proposed changes accounts for tubes that may leak during design
basis accidents. The accident induced leakage criterion limits this
leakage to no more than the value assumed in the accident analysis.
The SG performance criteria proposed change[s] to the TS[s]
identify the standards against which tube integrity is to be
measured. Meeting the performance criteria provides reasonable
assurance that the SG tubing will remain capable of fulfilling its
specific safety function of maintaining reactor coolant pressure
boundary integrity throughout each operating cycle and in the
unlikely event of a design basis accident. The performance criteria
are only a part of the SG Program required by the proposed change to
the TS[s]. The program, defined by NEI [Nuclear Energy Institute]
97-06, Steam Generator Program Guidelines, includes a framework that
incorporates a balance of prevention, inspection, evaluation,
repair, and leakage monitoring. The proposed changes do not,
therefore, significantly increase the probability of an accident
previously evaluated.
The consequences of design basis accidents are, in part,
functions of the DOSE EQUIVALENT I-131 in the primary coolant and
the primary to secondary LEAKAGE rates resulting from an accident.
Therefore, limits are included in the plant technical specifications
for operational leakage and for DOSE EQUIVALENT I-131 in primary
coolant to ensure the plant is operated within its analyzed
condition. The typical analysis of the limiting design basis
accident assumes that primary to secondary leak rate after the
accident is 1 gallon per minute with no more than [500 gallons per
day or 720 gallons per day] in any one SG, and that the reactor
coolant activity levels of DOSE EQUIVALENT I-131 are at the TS
values before the accident.
The proposed change does not affect the design of the SGs, their
method of operation, or primary coolant chemistry controls. The
proposed approach updates the current TSs and enhances the
requirements for SG inspections. The proposed change does not
adversely impact any other previously evaluated design basis
accident and is an improvement over the current TSs.
Therefore, the proposed change does not affect the consequences
of a SGTR accident and the probability of such an accident is
reduced. In addition, the proposed changes do not affect the
consequences of an MSLB, rod ejection, or a reactor coolant pump
locked rotor event, or other previously evaluated accident.
Criterion 2--The proposed change does not create the possibility
of a new or different
[[Page 40747]]
kind of accident from any previously evaluated.
The proposed performance based requirements are an improvement
over the requirements imposed by the current technical
specifications. Implementation of the proposed SG Program will not
introduce any adverse changes to the plant design basis or
postulated accidents resulting from potential tube degradation. The
result of the implementation of the SG Program will be an
enhancement of SG tube performance. Primary to secondary LEAKAGE
that may be experienced during all plant conditions will be
monitored to ensure it remains within current accident analysis
assumptions.
The proposed change does not affect the design of the SGs, their
method of operation, or primary or secondary coolant chemistry
controls. In addition, the proposed change does not impact any other
plant system or component. The change enhances SG inspection
requirements.
Therefore, the proposed change does not create the possibility
of a new or different type of accident from any accident previously
evaluated.
Criterion 3--The proposed change does not involve a significant
reduction in the margin of safety.
The SG tubes in pressurized water reactors are an integral part
of the reactor coolant pressure boundary and, as such, are relied
upon to maintain the primary system's pressure and inventory. As
part of the reactor coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as a heat transfer surface
between the primary and secondary systems such that residual heat
can be removed from the primary system. In addition, the SG tubes
isolate the radioactive fission products in the primary coolant from
the secondary system. In summary, the safety function of an SG is
maintained by ensuring the integrity of its tubes. Steam generator
tube integrity is a function of the design, environment, and the
physical condition of the tube. The proposed change does not affect
tube design or operating environment. The proposed change is
expected to result in an improvement in the tube integrity by
implementing the SG Program to manage SG tube inspection,
assessment, repair, and plugging. The requirements established by
the SG Program are consistent with those in the applicable design
codes and standards and are an improvement over the requirements in
the current TSs.
For the above reasons, the margin of safety is not changed and
overall plant safety will be enhanced by the proposed change to the
TS.
Based upon the reasoning presented above it appears that the three
standards of 10 CFR 50.92(c) are satisfied. Therefore, the NRC staff
proposes to determine that the amendment request involves no
significant hazards consideration.
Attorney for licensee: M.S. Ross, Attorney, Florida Power & Light,
P.O. Box 14000, Juno Beach, Florida 33408-0420.
NRC Branch Chief: Michael L. Marshall, Jr.
Florida Power and Light Company, Docket No. 50-389, St. Lucie Plant,
Unit No. 2, St. Lucie County, Florida
Date of amendment request: May 25, 2006.
Description of amendment request: The proposed amendment would
revise the Technical Specifications (TSs) consistent with the NRC-
approved Revision 4 to TS Task Force (TSTF) Standard TS Change
Traveler, TSTF-449, ``Steam Generator Tube Integrity.''
The NRC staff issued a notice of opportunity for comment in the
Federal Register on March 2, 2005 (70 FR 10298), on possible amendments
adopting TSTF-449, including a model safety evaluation and model no
significant hazards consideration (NSHC) determination, using the
consolidated line item improvement process. The NRC staff subsequently
issued a notice of availability of the models for referencing in
license amendment applications in the Federal Register on May 6, 2005
(70 FR 24126). The licensee affirmed the applicability of the following
NSHC determination in its application dated May 25, 2006.
Basis for proposed no significant hazards consideration
determination: As required by 10 CFR 50.91(a), an analysis of the issue
of no significant hazards consideration is presented below:
Criterion 1--The proposed change does not involve a significant
increase in the probability or consequences of an accident
previously evaluated.
The proposed change requires a SG [Steam Generator] Program that
includes performance criteria that will provide reasonable assurance
that the SG tubing will retain integrity over the full range of
operating conditions (including startup, operation in the power
range, hot standby, cooldown and all anticipated transients included
in the design specification). The SG performance criteria are based
on tube structural integrity, accident induced leakage, and
operational LEAKAGE.
A[n] SGTR [steam generator tube rupture] event is one of the
design basis accidents that are analyzed as part of a plant's
licensing basis. In the analysis of a[n] SGTR event, a bounding
primary to secondary LEAKAGE rate equal to the operational LEAKAGE
rate limits in the licensing basis plus the LEAKAGE rate associated
with a double-ended rupture of a single tube is assumed.
For other design basis accidents such as MSLB [main steamline
break], rod ejection, and reactor coolant pump locked rotor the
tubes are assumed to retain their structural integrity (i.e., they
are assumed not to rupture). These analyses typically assume that
primary to secondary LEAKAGE for all SGs is 1 gallon per minute or
increases to 1 gallon per minute as a result of accident induced
stresses. The accident induced leakage criterion introduced by the
proposed changes accounts for tubes that may leak during design
basis accidents. The accident induced leakage criterion limits this
leakage to no more than the value assumed in the accident analysis.
The SG performance criteria proposed change[s] to the TS[s]
identify the standards against which tube integrity is to be
measured. Meeting the performance criteria provides reasonable
assurance that the SG tubing will remain capable of fulfilling its
specific safety function of maintaining reactor coolant pressure
boundary integrity throughout each operating cycle and in the
unlikely event of a design basis accident. The performance criteria
are only a part of the SG Program required by the proposed change to
the TS[s]. The program, defined by NEI [Nuclear Energy Institute]
97-06, Steam Generator Program Guidelines, includes a framework that
incorporates a balance of prevention, inspection, evaluation,
repair, and leakage monitoring. The proposed changes do not,
therefore, significantly increase the probability of an accident
previously evaluated.
The consequences of design basis accidents are, in part,
functions of the DOSE EQUIVALENT I-131 in the primary coolant and
the primary to secondary LEAKAGE rates resulting from an accident.
Therefore, limits are included in the plant technical specifications
for operational leakage and for DOSE EQUIVALENT I-131 in primary
coolant to ensure the plant is operated within its analyzed
condition. The typical analysis of the limiting design basis
accident assumes that primary to secondary leak rate after the
accident is 1 gallon per minute with no more than [500 gallons per
day or 720 gallons per day] in any one SG, and that the reactor
coolant activity levels of DOSE EQUIVALENT I-131 are at the TS
values before the accident.
The proposed change does not affect the design of the SGs, their
method of operation, or primary coolant chemistry controls. The
proposed approach updates the current TSs and enhances the
requirements for SG inspections. The proposed change does not
adversely impact any other previously evaluated design basis
accident and is an improvement over the current TSs.
Therefore, the proposed change does not affect the consequences
of a SGTR accident and the probability of such an accident is
reduced. In addition, the proposed changes do not affect the
consequences of an MSLB, rod ejection, or a reactor coolant pump
locked rotor event, or other previously evaluated accident.
Criterion 2--The proposed change does not create the possibility
of a new or different kind of accident from any previously
evaluated.
The proposed performance based requirements are an improvement
over the requirements imposed by the current technical
specifications. Implementation of the proposed SG Program will not
introduce any adverse changes to the plant design basis or
postulated accidents resulting from potential tube degradation. The
result of the implementation of the SG Program will be an
[[Page 40748]]
enhancement of SG tube performance. Primary to secondary LEAKAGE
that may be experienced during all plant conditions will be
monitored to ensure it remains within current accident analysis
assumptions.
The proposed change does not affect the design of the SGs, their
method of operation, or primary or secondary coolant chemistry
controls. In addition, the proposed change does not impact any other
plant system or component. The change enhances SG inspection
requirements.
Therefore, the proposed change does not create the possibility
of a new or different type of accident from any accident previously
evaluated.
Criterion 3--The proposed change does not involve a significant
reduction in the margin of safety.
The SG tubes in pressurized water reactors are an integral part
of the reactor coolant pressure boundary and, as such, are relied
upon to maintain the primary system's pressure and inventory. As
part of the reactor coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as a heat transfer surface
between the primary and secondary systems such that residual heat
can be removed from the primary system. In addition, the SG tubes
isolate the radioactive fission products in the primary coolant from
the secondary system. In summary, the safety function of an SG is
maintained by ensuring the integrity of its tubes. Steam generator
tube integrity is a function of the design, environment, and the
physical condition of the tube. The proposed change does not affect
tube design or operating environment. The proposed change is
expected to result in an improvement in the tube integrity by
implementing the SG Program to manage SG tube inspection,
assessment, repair, and plugging. The requirements established by
the SG Program are consistent with those in the applicable design
codes and standards and are an improvement over the requirements in
the current TSs.
For the above reasons, the margin of safety is not changed and
overall plant safety will be enhanced by the proposed change to the
TS.
Based upon the reasoning presented above it appears that the three
standards of 10 CFR 50.92(c) are satisfied. Therefore, the NRC staff
proposes to determine that the amendment request involves no
significant hazards consideration.
Attorney for licensee: M.S. Ross, Attorney, Florida Power & Light,
P.O. Box 14000, Juno Beach, Florida 33408-0420.
NRC Branch Chief: Michael L. Marshall, Jr.
Florida Power and Light Company, Docket Nos. 50-250 and 50-251, Turkey
Point Plant, Units 3 and 4, Miami-Dade County, Florida
Date of amendment request: April 27, 2006.
Description of amendment request: The proposed amendment would
revise the Technical Specifications (TSs) consistent with the NRC-
approved Revision 4 to TS Task Force (TSTF) Standard TS Change
Traveler, TSTF-449, ``Steam Generator Tube Integrity.''
The NRC staff issued a notice of opportunity for comment in the
Federal Register on March 2, 2005 (70 FR 10298), on possible amendments
adopting TSTF-449, including a model safety evaluation and model no
significant hazards consideration (NSHC) determination, using the
consolidated line item improvement process. The NRC staff subsequently
issued a notice of availability of the models for referencing in
license amendment applications in the Federal Register on May 6, 2005
(70 FR 24126). The licensee affirmed the applicability of the following
NSHC determination in its application dated April 27, 2006.
Basis for proposed no significant hazards consideration
determination: As required by 10 CFR 50.91(a), an analysis of the issue
of no significant hazards consideration is presented below:
Criterion 1--The proposed change does not involve a significant
increase in the probability or consequences of an accident
previously evaluated.
The proposed change requires a SG [Steam Generator] Program that
includes performance criteria that will provide reasonable assurance
that the SG tubing will retain integrity over the full range of
operating conditions (including startup, operation in the power
range, hot standby, cooldown and all anticipated transients included
in the design specification). The SG performance criteria are based
on tube structural integrity, accident induced leakage, and
operational LEAKAGE.
A[n] SGTR [steam generator tube rupture] event is one of the
design basis accidents that are analyzed as part of a plant's
licensing basis. In the analysis of a[n] SGTR event, a bounding
primary to secondary LEAKAGE rate equal to the operational LEAKAGE
rate limits in the licensing basis plus the LEAKAGE rate associated
with a double-ended rupture of a single tube is assumed.
For other design basis accidents such as MSLB [main steamline
break], rod ejection, and reactor coolant pump locked rotor the
tubes are assumed to retain their structural integrity (i.e., they
are assumed not to rupture). These analyses typically assume that
primary to secondary LEAKAGE for all SGs is 1 gallon per minute or
increases to 1 gallon per minute as a result of accident induced
stresses. The accident induced leakage criterion introduced by the
proposed changes accounts for tubes that may leak during design
basis accidents. The accident induced leakage criterion limits this
leakage to no more than the value assumed in the accident analysis.
The SG performance criteria proposed change[s] to the TS[s]
identify the standards against which tube integrity is to be
measured. Meeting the performance criteria provides reasonable
assurance that the SG tubing will remain capable of fulfilling its
specific safety function of maintaining reactor coolant pressure
boundary integrity throughout each operating cycle and in the
unlikely event of a design basis accident. The performance criteria
are only a part of the SG Program required by the proposed change to
the TS[s]. The program, defined by NEI [Nuclear Energy Institute]
97-06, Steam Generator Program Guidelines, includes a framework that
incorporates a balance of prevention, inspection, evaluation,
repair, and leakage monitoring. The proposed changes do not,
therefore, significantly increase the probability of an accident
previously evaluated.
The consequences of design basis accidents are, in part,
functions of the DOSE EQUIVALENT I-131 in the primary coolant and
the primary to secondary LEAKAGE rates resulting from an accident.
Therefore, limits are included in the plant technical specifications
for operational leakage and for DOSE EQUIVALENT I-131 in primary
coolant to ensure the plant is operated within its analyzed
condition. The typical analysis of the limiting design basis
accident assumes that primary to secondary leak rate after the
accident is 1 gallon per minute with no more than [500 gallons per
day or 720 gallons per day] in any one SG, and that the reactor
coolant activity levels of DOSE EQUIVALENT I-131 are at the TS
values before the accident.
The proposed change does not affect the design of the SGs, their
method of operation, or primary coolant chemistry controls. The
proposed approach updates the current TSs and enhances the
requirements for SG inspections. The proposed change does not
adversely impact any other previously evaluated design basis
accident and is an improvement over the current TSs.
Therefore, the proposed change does not affect the consequences
of a SGTR accident and the probability of such an accident is
reduced. In addition, the proposed changes do not affect the
consequences of an MSLB, rod ejection, or a reactor coolant pump
locked rotor event, or other previously evaluated accident.
Criterion 2--The proposed change does not create the possibility
of a new or different kind of accident from any previously
evaluated.
The proposed performance based requirements are an improvement
over the requirements imposed by the current technical
specifications. Implementation of the proposed SG Program will not
introduce any adverse changes to the plant design basis or
postulated accidents resulting from potential tube degradation. The
result of the implementation of the SG Program will be an
enhancement of SG tube performance. Primary to secondary LEAKAGE
that may be experienced during all plant conditions will be
monitored to ensure it remains within current accident analysis
assumptions.
The proposed change does not affect the design of the SGs, their
method of operation, or primary or secondary coolant chemistry
controls. In addition, the proposed change does not impact any other
plant system or component. The change enhances SG inspection
requirements.
[[Page 40749]]
Therefore, the proposed change does not create the possibility
of a new or different type of accident from any accident previously
evaluated.
Criterion 3--The proposed change does not involve a significant
reduction in the margin of safety.
The SG tubes in pressurized water reactors are an integral part
of the reactor coolant pressure boundary and, as such, are relied
upon to maintain the primary system's pressure and inventory. As
part of the reactor coolant pressure boundary, the SG tubes are
unique in that they are also relied upon as a heat transfer surface
between the primary and secondary systems such that residual heat
can be removed from the primary system. In addition, the SG tubes
isolate the radioactive fission products in the primary coolant from
the secondary system. In summary, the safety function of an SG is
maintained by ensuring the integrity of its tubes. Steam generator
tube integrity is a function of the design, environment, and the
physical condition of the tube. The proposed change does not affect
tube design or operating environment. The proposed change is
expected to result in an improvement in the tube integrity by
implementing the SG Program to manage SG tube inspection,
assessment, repair, and plugging. The requirements established by
the SG Program are consistent with those in the applicable design
codes and standards and are an improvement over the requirements in
the current TSs.
For the above reasons, the margin of safety is not changed and
overall plant safety will be enhanced by the proposed change to the
TS.
Based upon the reasoning presented above it appears that the three
standards of 10 CFR 50.92(c) are satisfied. Therefore, the NRC staff
proposes to determine that the amendment request involves no
significant hazards consideration.
Attorney for licensee: M.S. Ross, Attorney, Florida Power & Light,
P.O. Box 14000, Juno Beach, Florida 33408-0420.
NRC Branch Chief: Michael L. Marshall, Jr.
Nine Mile Point Nuclear Station, LLC, Docket No. 50-220, Nine Mile
Point Nuclear Station Unit No. 1, Oswego County, New York
Date of amendment request: January 18, 2006.
Description of amendment request: The proposed amendment would
delete the reference to the hydrogen monitors in Technical
Specification (TS) 3.6.11, ``Accident Monitoring Instrumentation''
consistent with the NRC-approved Industry/Technical Specification Task
Force (TSTF) Standard Technical Specification Change Traveler, TSTF-
447, ``Elimination of Hydrogen Recombiners and Change to Hydrogen and
Oxygen Monitors.''
The NRC staff issued a notice of availability of ``Model
Application Concerning Technical Specification Improvement To Eliminate
Hydrogen Recombiner Requirement, and Relax the Hydrogen and Oxygen
Monitor Requirements for Light Water Reactors Using the Consolidated
Line Item Improvement Process (CLIIP)'', in the Federal Register on
September 25, 2003 (68 FR 55416). The notice included a model safety
evaluation (SE), a model no significant hazards consideration (NSHC)
determination, and a model application.
Basis for proposed no significant hazards consideration
determination: As required by 10 CFR 50.91(a), the licensee has
provided its analysis of the issue of no significant hazards
consideration, by confirming the applicability of the model NSHC
determination to NMP-1 and incorporating it by reference in its
application. The model NSHC determination is presented below:
Criterion 1--The Proposed Change Does Not Involve a Significant
Increase in the Probability or Consequences of an Accident
Previously Evaluated.
The revised 10 CFR 50.44 no longer defines a design-basis loss-
of-coolant accident (LOCA) hydrogen release, and eliminates
requirements for hydrogen control systems to mitigate such a
release. The installation of hydrogen recombiners and/or vent and
purge systems required by 10 CFR 50.44(b)(3) was intended to address
the limited quantity and rate of hydrogen generation that was
postulated from a design-basis LOCA. The Commission has found that
this hydrogen release is not risk-significant because the design-
basis LOCA hydrogen release does not contribute to the conditional
probability of a large release up to approximately 24 hours after
the onset of core damage. In addition, these systems were
ineffective at mitigating hydrogen releases from risk-significant
accident sequences that could threaten containment integrity.
With the elimination of the design-basis LOCA hydrogen release,
hydrogen [and oxygen] monitors are no longer required to mitigate
design-basis accidents and, therefore, the hydrogen monitors do not
meet the definition of a safety-related component as defined in 10
CFR 50.2. RG [Regulatory Guide] 1.97 Category 1, is intended for key
variables that most directly indicate the accomplishment of a safety
function for design-basis accident events. The hydrogen [and oxygen]
monitors no longer meet the definition of Category 1 in RG 1.97. As
part of the rulemaking to revise 10 CFR 50.44 the Commission found
that Category 3, as defined in RG 1.97, is an appropriate
categorization for the hydrogen monitors because the monitors are
required to diagnose the course of beyond design-basis accidents.
[Also, as part of the rulemaking to revise 10 CFR 50.44, the
Commission found that Category 2, as defined in RG 1.97, is an
appropriate categorization for the oxygen monitors, because the
monitors are required to verify the status of the inert
containment.]
The regulatory requirements for the hydrogen [and oxygen]
monitors can be relaxed without degrading the plant emergency
response. The emergency response, in this sense, refers to the
methodologies used in ascertaining the condition of the reactor
core, mitigating the consequences of an accident, assessing and
projecting offsite releases of radioactivity, and establishing
protective action recommendations to be communicated to offsite
authorities. Classification of the hydrogen monitors as Category 3,
[classification of the oxygen monitors as Category 2] and removal of
the hydrogen [and oxygen] monitors from TS will not prevent an
accident management strategy through the use of the SAMGs [severe
accident management guidelines], the emergency plan (EP), the
emergency operating procedures (EOP), and site survey monitoring
that support modification of emergency plan protective action
recommendations (PARs).
Therefore, the elimination of the hydrogen recombiner
requirements and relaxation of the hydrogen [and oxygen] monitor
requirements, including removal of these requirements from TS, does
not involve a significant increase in the probability or the
consequences of any accident previously evaluated.
Criterion 2--The Proposed Change Does Not Create the Possibility
of a New or Different Kind of Accident From Any Previously
Evaluated.
The elimination of the hydrogen recombiner requirements and
relaxation of the hydrogen [and oxygen] monitor requirements,
including removal of these requirements from TS, will not result in
any failure mode not previously analyzed. The hydrogen recombiner
and hydrogen [and oxygen] monitor equipment was intended to mitigate
a design-basis hydrogen release. The hydrogen recombiner and
hydrogen [and oxygen] monitor equipment are not considered accident
precursors, nor does their existence or elimination have any adverse
impact on the pre-accident state of the reactor core or post
accident confinement of radionuclides within the containment
building.
Therefore, this change does not create the possibility of a new
or different kind of accident from any previously evaluated.
Criterion 3--The Proposed Change Does Not Involve a Significant
Reduction in [a] Margin of Safety.
The elimination of the hydrogen recombiner requirements and
relaxation of the hydrogen [and oxygen] monitor requirements,
including removal of these requirements from TS, in light of
existing plant equipment, instrumentation, procedures, and programs
that provide effective mitigation of and recovery from reactor
accidents, results in a neutral impact to the margin of safety.
The installation of hydrogen recombiners and/or vent and purge
systems required by 10 CFR 50.44(b)(3) was intended to address the
limited quantity and rate of hydrogen generation that was postulated
from a design-basis LOCA. The Commission has found that
[[Page 40750]]
this hydrogen release is not risk-significant because the design-
basis LOCA hydrogen release does not contribute to the conditional
probability of a large release up to approximately 24 hours after
the onset of core damage.
Category 3 hydrogen monitors are adequate to provide rapid
assessment of current reactor core conditions and the direction of
degradation while effectively responding to the event in order to
mitigate the consequences of the accident. The intent of the
requirements established as a result of the TMI [Three Mile Island],
Unit 2 accident can be adequately met without reliance on safety-
related hydrogen monitors.
[Category 2 oxygen monitors are adequate to verify the status of
an inerted containment.]
Therefore, this change does not involve a significant reduction
in [a] margin of safety. [The intent of the requirements established
as a result of the TMI, Unit 2 accident can be adequately met
without reliance on safety-related oxygen monitors.] Removal of
hydrogen [and oxygen] monitoring from TS will not result in a
significant reduction in their functionality, reliability, and
availability.
The NRC staff has reviewed the model NSHC determination and its
applicability to NMP-1. Based on this review, the NRC staff proposes to
determine that the amendment request involves no significant hazards
consideration.
Attorney for licensee: Mark J. Wetterhahn, Esquire, Winston &
Strawn, 1700 K Street, NW., Washington, DC 20006.
NRC Branch Chief: Richard J. Laufer.
Nuclear Management Company, LLC, Docket Nos. 50-266 and 50-301, Point
Beach Nuclear Plant, Units 1 and 2, Town of Two Creeks, Manitowoc
County, Wisconsin
Date of amendment request: June 6, 2006.
Description of amendment request: The proposed amendments would
revise the design basis as described in the Point Beach Nuclear Plant
Final Safety Analysis Report (FSAR) by incorporating an updated
analysis for satisfying the reactor vessel Charpy upper-shelf energy
requirements of 10 CFR part 50, Appendix G, Section IV.A.1.
Basis for proposed no significant hazards consideration
determination: As required by 10 CFR 50.91(a), the licensee has
provided its analysis of the issue of no significant hazards
consideration which is presented below:
1. Would the proposed amendment involve a significant increase
in the probability or consequences of any accident previously
evaluated?
The proposed change incorporates the updated analysis for
satisfying the reactor vessel Charpy upper-shelf energy requirements
of 10 CFR part 50, Appendix G, Section IV.A.1 into the FSAR. The
proposed change does not adversely affect accident initiators or
precursors nor alter the design assumptions, conditions, or the
manner in which the plant is operated and maintained. The proposed
change does not alter or prevent the ability of structures, systems,
and components from performing their intended function to mitigate
the consequences of an initiating event within the assumed
acceptance limits. The proposed change does not affect the source
term, containment isolation, or radiological release assumptions
used in evaluating the radiological consequences of an accident
previously evaluated. Further, the proposed change does not increase
the types or amounts of radioactive effluent that may be released
offsite, nor significantly increase individual or cumulative
occupational/public radiation exposures. The proposed change is
consistent with safety analysis assumptions and resultant
consequences. Therefore, it is concluded that this change does not
significantly increase the probability of occurrence of an accident
previously evaluated.
2. Would the proposed amendment create the possibility of a new
or different kind of accident from any accident previously
evaluated?
The proposed change incorporates the updated analysis for
satisfying the reactor vessel Charpy upper-shelf energy requirements
of 10 CFR part 50, Appendix G, Section IV.A.1 into the FSAR. The
change does not impose any new or different requirements or
eliminate any existing requirements. The change does not alter
assumptions made in the safety analysis. The proposed change is
consistent with the safety analysis assumptions and current plant
operating practice. Therefore, the proposed change would not create
the possibility of a new or different kind of accident from any
previously evaluated.
3. Would the proposed amendment result in a significant
reduction in a margin of safety?
The proposed change incorporates the updated analysis for
satisfying the reactor vessel Charpy upper-shelf energy requirements
of 10 CFR part 50, Appendix G, Section IV.A.1 into the FSAR. The
proposed change does not alter the manner in which safety limits,
limiting safety system settings or limiting conditions for operation
are determined. The setpoints at which protective actions are
initiated are not altered by the proposed change. Therefore, the
proposed amendment does not result in a significant reduction in a
margin of safety.
The