[Federal Register Volume 66, Number 229 (Wednesday, November 28, 2001)]
[Notices]
[Pages 59495-59498]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 01-29585]


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NUCLEAR REGULATORY COMMISSION

[Docket No. 50-333]


Entergy Nuclear Operations, Inc.; Notice of Consideration of 
Issuance of Amendment to Facility Operating License and Opportunity for 
a Hearing

    The U.S. Nuclear Regulatory Commission (the Commission) is 
considering issuance of an amendment to Facility Operating License No. 
DPR-59, issued to Entergy Nuclear Operations, Inc. (ENO or the 
licensee) for operation of the James A. FitzPatrick Nuclear Power 
Plant, (FitzPatrick), located in Oswego County, New York.
    The initial notice of consideration of issuance of amendment to 
facility operating license and opportunity for hearing was originally 
published in the Federal Register (64 FR 60854) on November 8, 1999, 
and corrected in the Federal Register (64 FR 69574) on December 13, 
1999. The information included in the supplemental letters indicates 
the original notice, that included 13 proposed beyond-scope issues 
(BSls) to the improved Technical Specifications (ITS) conversion, needs 
to be expanded and revised to include a total of thirty one BSls and 
requires re-notice in the Federal Register. This notice supercedes the 
previous notice.
    The proposed amendment, requested by the Power Authority of the 
State of New York, the former licensee, in a letter dated March 31, 
1999, as supplemented by letters dated May 20, June 1, July 14, October 
14, 1999, February 11, April 4, April 13, June 30, July 31, September 
12, September 13, and October 23, 2000, represents a full conversion 
from the current Technical Specifications (CTS) to a set of ITS based 
on NUREG-1433, ``Standard Technical Specifications (STS) for General 
Electric Plants, BWR/4'' Revision 1, dated April 1995. On November 21, 
2000, the Power Authority of the State of New York's (PASNY's) 
ownership interest in FitzPatrick was transferred to Entergy Nuclear 
FitzPatrick, LLC, to possess and use FitzPatrick and to Entergy Nuclear 
Operations (ENO), Inc. to possess, use and operate FitzPatrick. By 
letter dated January 26, 2001, ENO requested that the NRC continue to 
review and act on all requests before the Commission which had been 
submitted by PASNY before the transfer. ENO has supplemented the 
original application with supplements by letter dated February 7, 
February 20, May 31 and August 6, 2001. NUREG-1433 has been developed 
by the Commission's staff through working groups composed of both NRC 
staff members and industry representatives, and has been endorsed by 
the staff as part of an industry-wide initiative to standardize and 
improve the Technical Specifications (TSs) for nuclear power plants. As 
part of this submittal, the licensee has applied the criteria contained 
in the Commission's ``Final Policy Statement on Technical Specification 
Improvements for Nuclear Power Reactors (Final Policy Statement),'' 
published in the Federal Register on July 22, 1993 (58 FR 39132), to 
the CTS and using NUREG-1433 as a basis, proposed an ITS for 
FitzPatrick. The criteria in the Final Policy Statement was 
subsequently added to 10 CFR 50.36, ``Technical Specifications,'' in a 
rule change that was published in the Federal Register on July 19, 1995 
(60 FR 36953) and became effective on August 18, 1995.
    The licensee has categorized the proposed changes to the CTS into 
four general groupings. These groupings are characterized as 
administrative changes, relocated changes, more restrictive changes and 
less restrictive changes.
    Administrative changes are those that involve restructuring, 
renumbering, rewording interpretation and complex rearranging of 
requirements and other

[[Page 59496]]

changes not affecting technical content or substantially revising an 
operating requirement. The reformatting, renumbering and rewording 
process reflects the attributes of NUREG-1433 and does not involve 
technical changes to the CTS. The proposed changes include: (a) 
Providing the appropriate numbers, etc., for NUREG-1433 bracketed 
information (information that must be supplied on a plant-specific 
basis, and which may change from plant to plant), (b) identifying 
plant-specific wording for system names, etc., and (c) changing NUREG-
1433 section wording to conform to existing licensee practices. Such 
changes are administrative in nature and do not impact initiators of 
analyzed events or assumed mitigation of accident or transient events.
    Relocated changes are those involving relocation of requirements 
and surveillances for structures, systems, components, or variables 
that do not meet the criteria for inclusion in TSs. Relocated changes 
are those CTS requirements that do not satisfy or fall within any of 
the four criteria specified in the 10 CFR 50.36(c)(2)(ii) and may be 
relocated to appropriate licensee-controlled documents.
    The licensee's application of the screening criteria is described 
in the attachment of the licensee's March 31, 1999, submittal, which is 
entitled, ``Application of NRC Selection Criteria to James A. 
FitzPatrick Nuclear Power Plant Technical Specifications'' (Split 
Report) in Volume 1 of the submittal. The affected structures, systems, 
components or variables are not assumed to be initiators of analyzed 
events and are not assumed to mitigate accident or transient events. 
The requirements and surveillances for these affected structures, 
systems, components, or variables will be relocated from the TSs to 
administratively controlled documents such as the quality assurance 
program, the final safety analysis report (FSAR), the ITS BASES, the 
Technical Requirements Manual (TRM) that is incorporated by reference 
in the FSAR, the Core Operating Limits Report (COLR), the Offsite Dose 
Calculation Manual (ODCM), the Inservice Testing (IST) Program, or 
other licensee-controlled documents. Changes made to these documents 
will be made pursuant to 10 CFR 50.59 or other appropriate control 
mechanisms, and may be made without prior NRC review and approval. In 
addition the affected structures, systems, components, or variables are 
addressed in existing surveillance procedures that are also subject to 
10 CFR 50.59. These proposed changes will not impose or eliminate any 
requirements.
    More restrictive changes are those involving more stringent 
requirements compared to the CTS for operation of the facility. These 
more stringent requirements do not result in operation that will alter 
assumptions relative to the mitigation of an accident or transient 
event. The more restrictive requirements will not alter the operation 
of process variables, structures, systems, and components described in 
the safety analyses. For each requirement in the STS that is more 
restrictive than the CTS that the licensee proposes to adopt in the 
ITS, the licensee has provided an explanation as to why it has 
concluded that adopting the more restrictive requirement is desirable 
to ensure safe operation of the facility because of specific design 
features of the plant.
    Less restrictive changes are those where CTS requirements are 
relaxed or eliminated, or new plant operational flexibility is 
provided. The more significant ``less restrictive'' requirements are 
justified on a case-by-case basis. When requirements have been shown to 
provide little or no safety benefit, their removal from the TS may be 
appropriate. In most cases, relaxations previously granted to 
individual plants on a plant-specific basis were the result of (a) 
generic NRC actions, (b) new NRC staff positions that have evolved from 
technological advancements and operating experience, or (c) resolution 
of the Owners Groups' comments on the Improved standard Technical 
Specifications. Generic relaxations contained in NUREG-1433 were 
reviewed by the staff and found to be acceptable because they are 
consistent with current licensing practices and NRC regulations. The 
licensee's design is being reviewed to determine if the specific design 
basis and licensing basis are consistent with the technical basis for 
the model requirements in NUREG-1433, thus providing a basis for the 
ITS, or if relaxation of the requirements in the CTS is warranted based 
on the justification provided by the licensee.
    These administrative, relocated, more restrictive, and less 
restrictive changes to the requirements of the CTS do not result in 
operations that will alter assumptions relative to mitigation of an 
analyzed accident or transient event.
    In addition to the proposed changes solely involving the 
conversion, there are also changes proposed that are different to the 
requirements in both the CTS and the Standard Technical Specifications 
(STS) NUREG-1433. These proposed beyond-scope issues to the its 
conversion are as follows:
    1. ITS 3.3.1.1, Reactor Protection System (RPS) Instrumentation 
Function 5, reactor scram on main steam isolation valve (MSIV) closure. 
The trip setting valve was changed from less than or equal to 10 
percent (in the CTS) to less than or equal to 14 percent in the ITS.
    2. ITS 3.3.1.1 changed the CTS allowable values for turbine stop 
valve closure, the turbine control valve fast closure and the EHC oil 
pressure low functions setpoints based on recent setpoint calculations.
    3. ITS 3.3.3.1, Suppression Pool Water Temperature is modified by 
footnote (c), which states : ``A channel requires 15 to 16 RTDs to be 
OPERABLE.'' This results in a CTS change and a deviation from the STS.
    4. ITS 3.3.4.1 changes the CTS and ISTS channel configuration from 
2 channels per trip system to 4 channels in one trip system.
    5. ITS 3.3.5.1 changed the CTS allowable values for CS pump flow, 
LPCI pressure, LPCI pump flow, HPCI vessel water level high and HPCI 
pump discharge flow low based on recent setpoint calculations.
    6. ITS 3.3.5.1, Automatic Depressurization System (ADS) initiation 
timer and the containment Spray (CS) and Low-Pressure Coolant Injection 
(LPCI) pump start timer values were changed from the CTS and the ISTS 
and tolerances relaxed to allow the extension of calibration Frequency 
to 24 months in the ITS.
    7. ITS 3.3.5.1 changed CTS Table 3.2-2 Item 9, Reactor Low 
Pressure, LPCI and Core Spray Injection Valve Open Permissive of >450 
psig to >410 psig in ITS Table 3.3.4.1-1 Functions 1.c and 2.c.
    8. ITS 3.3.5.1 changed CTS Table 3.3-2, Item 5, Reactor Low Level 
Containment spray Interlock trip level setting of >~0.0 inch to >~1.0 
inch in ITS Table 3.3.5.1-1.
    9. ITS 3.3.5.1 changed the trip setpoint Allowable Values in CTS 
Table 3.2-2 for the Core Spray Pump Start Timer (item 11), the RHR LPCI 
Pump Start Timer (item 12, and the Auto Blowdown Timer (item 13) in ITS 
Table 3.3.5.1-1 Functions 1.d, 2.f, 4.b and 5.b to reflect values 
corresponding to a 6-month to 24-month reduction in calibration 
Frequency.
    10. ITS 3.3.5.1 changed the trip setpoint Allowable Values in CTS 
Table 3.2-1 for the suppression Chamber High Level (item 13) in ITS 
Table 3.3.5.1-1 Function 3.e to 14.5 inches which is ~6 inches above 
normal level.
    11. ITS 3.3.5.1 changed the CTS Table 3.2-2 trip level setting for 
Item 24, Reactor Low-pressure from 285 to 335

[[Page 59497]]

psig to >~300 psig in ITS Table 3.3.5.1 Function 2.d.
    12. ITS 3.3.6.1 changed the Allowable Values in CTS Table 3.2-1 for 
the HPCI Turbine steam Line High Flow to reflect values corresponding 
to 160 to 161 inches of water differential pressure (dp) in ITS TABLE 
3.3.6.1-1 Function 3.a.
    13. ITS 3.3.6.1 changed the trip setpoint Allowable Value ``HPCI/
Reactor Core Isolation cooling (RCIC) Steam Line Low Pressure'' in ITS 
Table 3.3.6.1-1 Function 3.b and 4.b to reflect values corresponding to 
>60 and ~90 for HPCI and >61 and ~90 for RCIC.
    14. ITS 3.3.6.1 changed the CTS allowable values of setpoint 
temperatures for the RWCU, HPCI, and RCIC.
    15. ITS 3.3.6.1 changed the CTS allowable values for the setpoints 
for main steam line flow high, main steam tunnel area temperature high, 
HPCI steam line flow high, HPCI turbine exhaust diaphragm pressure 
high, HPCI steam line penetration (drywell entrance) area temperature 
high, HPCI steam line torus room area temperature high, HPCI equipment 
area temperature high, RHR heat exchanger A area temperature high, 
reactor building (RB) southwest area of elevation 272 feet temperature 
high, RCIC steam line flow high, RCIC steam supply line pressure low, 
RCIC turbine exhaust diaphragm pressure high RCIC steam supply line 
pressure low, RCIC turbine exhaust diaphragm pressure high, RCIC steam 
line steam line penetration (drywell entrance) area temperature high, 
RCIC steam line torus room area temperature high, RCIC equipment area 
temperature high, RWCU suction line penetration area temperature high, 
RWCU heat exchanger room area temperature high, RWCU pump area 
temperature high (Pumps A and B), and SDC reactor pressure high to be 
consistent with support setpoint calculations.
    16. ITS 3.3.7.3 changed the LCO section of the Bases consistent 
with the changes made to accommodate RAI 3.3.1.1-1.
    17. ITS 3.3.8.1 safety analysis section of the Bases has been 
changed to be consistent with changes made as a result of RAI 3.3.1-
1.SI
    18. ITS 3.3.8.2 changed the Trip Level Settings for Loss of Offsite 
Power (LOP) instrumentation listed in CTS Table 3.2.-2 to new ITS 
Allowable Values listed in ITS Table 3.3.8.1-1.
    19. ITS 3.3.8.2 changed CTS 4.9.G.3 setpoint or Allowable Value of 
>~108V to >109.9V in its SR 3.3.8.2.3.
    20. ITS 3.4.7 added an RHR Shutdown Cooling-Hot Shutdown 
specification to the ITS SPECIFICATION based on current licensing basis 
been restored to operable status within 30 days. ITS 3.3.3.1 ACTION B 
specifies initiating action in accordance with ITS 5.5.6 which relates 
to reporting requirements.
    21. ITS 3.4.9, Reactor Coolant System (RCS) Pressure/Temperature 
(P/T) Limits in CTS were changed to add a new alternate criteria in ITS 
to allow idle recirculating pump (loop) start if the operating loop is 
greater than 40 percent flow or if the idle loop is less than 40% flow 
for less than or equal to 30 minutes.
    22. ITS 3.5.1 and ITS 3.5.2, Emergency Core Cooling System (ECCS)-
Operating and Shutdown, High-Pressure Coolant Injection (HPCI) and 
Residual Heat Removal (RHR) LPCI pump flow rates in CTS were reduced to 
SAFER/GESTR-Loss-of-Coolant Accident (LOCA) flow rates in the ITS.
    23. ITS 3.5.3 adds an additional requirement to ITS SR 3.5.3.3 that 
requires the performance of the surveillance ``Once each startup prior 
to exceeding 25% RTP.''
    24. ITS 3.5.3 divides the existing CTS 4.5.E.1.d surveillance 
requirement that ``RCIC delivers at least 400 gpm against a system head 
corresponding to a reactor vessel pressure of 1195 psig to 150 psig'' 
into two separate Surveillance Requirements: ITS SR 3.4.3.5 and ITS SR 
3.5.3.6.
    25. ITS 3.6.1.1 deletes the CTS 4.7.A.1 requirement to inspect the 
interior surface of the drywell and suppression chamber above the water 
line every 24 months based on the inspection being required by the 
primary containment leakage rate testing program 3 times in 10 years.
    26. ITS SR 3.6.1.1.1 changes the note in the ISTS markup that LPCI 
and Core Spray air operated testable check valve leakage test failure 
does not result in an ITS SR 3.6.1.1.1 failure.
    27. ITS 3.6.1.3 changed CTS LPCI and CS testable check valve 
testing per Primary Containment Leakage Rate Testing (PCLRT) program 
(twice every 24 months).
    28. ITS SR 3.6.1.7.1, SR 3.6.1.7.2, and B 3.6.1.7 changes the 
frequency of performing a functional test of each required vacuum 
breaker from 31 days as indicated in the ISTS to a new schedule in 
accordance with the IST Program which is 92 days.
    29. ITS SR 3.6.2.3.2 was changed to add the word ``required'' to 
make it clearer that the SR is only applicable to the single RHR pump 
in a subsystem rather than both pumps in a subsystem that are provided 
by design.
    30. ITS 3.8.1, AC Sources--Operating, Condition D for two reserve 
circuits inoperable in CTS was changed to add new interim power 
reduction to less than or equal to 45 percent with a 36-hour Completion 
Time in the ITS.
    31. ITS 3.8.4, DC Sources--Operating (in CTS) was changed to allow 
8 hours to restore one inoperable source in the ITS.
    Before issuance of the proposed license amendments, the Commission 
will have made findings required by the Atomic Energy Act of 1954, as 
amended (the Act) and the commission's regulations.
    By December 28, 2001, 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 2.714, which is 
available at the Commission's Public Document Room, located at One 
White Flint North, 11555 Rockville Pike (first floor), Rockville, 
Maryland, or electronically on the Internet at the NRC Web site http://www.nrc.gov/NRC/CFR/index.html. If there are problems in accessing the 
document, contact the Public Document Room Reference staff at 1-800-
397-4209, 301-415-4737, or by e-mail to [email protected]. If a request for a 
hearing or petition for leave to intervene is filed by the above date, 
the Commission or an Atomic Safety and Licensing Board, designated by 
the Commission or by the Chairman of the Atomic Safety and Licensing 
Board Panel, will rule on the request and/or petition; and the 
Secretary or the designated Atomic Safety and Licensing Board will 
issue a notice of hearing or an appropriate order.
    As required by 10 CFR 2.714, 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 factors: (1) The nature of the petitioner's right under the 
Act to be made a party to the proceeding; (2) the nature and extent of 
the petitioner's property, financial, or other interest in the 
proceeding; and (3) the possible effect of any order which may be 
entered in the proceeding on the

[[Page 59498]]

petitioner's interest. The petition should also identify the specific 
aspect(s) of the subject matter of the proceeding as to which 
petitioner wishes to intervene. Any person who has filed a petition for 
leave to intervene or who has been admitted as a party may amend the 
petition without requesting leave of the Board up to 15 days prior to 
the first prehearing conference scheduled in the proceeding, but such 
an amended petition must satisfy the specificity requirements described 
above.
    Not later than 15 days prior to the first prehearing conference 
scheduled in the proceeding, a petitioner shall file a supplement to 
the petition to intervene which must include alist of the contentions 
which are sought to be litigated in the matter. Each contention must 
consist of a specific statement of the issue of law or fact to be 
raised or controverted. In addition, the petitioner shall provide a 
brief explanation of the bases of the contention and a concise 
statement of the alleged facts or expert opinion which support the 
contention and on which the petitioner intends to rely in proving the 
contention at the hearing. The petitioner must also provide references 
to those specific sources and documents of which the petitioner is 
aware and on which the petitioner intends to rely to establish those 
facts or expert opinion. Petitioner must provide 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 to relief. A 
petitioner who fails to file such a supplement which satisfies 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, including the opportunity to present evidence and cross-
examine witnesses.
    A request for a hearing and petition for leave to intervene must be 
filed with the Secretary of the Commission, U.S. Nuclear Regulatory 
Commission, Washington, DC 20555-0001, Attention: Rulemakings and 
Adjudications Staff, or may be delivered to the Commission's Public 
Document Room, located at One White Flint North, 11555 Rockville Pike 
(first floor), Rockville, Maryland, by the above date. A copy of the 
petition should also be sent to the Office of the General Counsel, U.S. 
Nuclear Regulatory Commission, Washington, DC 20555-0001, and to Mr. 
David E. Blabey, attorney for the licensee, 1633 Broadway, New York, 
New York 10019.
    Nontimely filings of petitions for leave to intervene, amended 
petitions, supplemental petitions and/or requests for hearing will not 
be entertained absent a determination by the commission, the presiding 
officer or the presiding Atomic Safety and Licensing Board that the 
petition and/or request should be granted based upon a balancing of the 
factors specified in 10CAR 2.714(a)(1)(l)-(v) and 2.714(d).
    If a request for a hearing is received, the Commission's staff may 
issue the amendment after it completes its technical review and prior 
to the completion of any required hearing if it publishes a further 
notice for public comment of its proposed finding of no significant 
hazards consideration in accordance with 10 CFR 50.91 and 50.92. For 
further details with respect to the proposed action, see the licensee's 
application dated March 31, 1999, as supplemented by letters dated May 
20, June 1, July 14, October 14, 1999, February 11, April 4, April 13, 
June 30, July 31, September 12, September 13, October 23, 2000, 
February 7, February 20, May 31, and August 6, 2001. Documents may be 
examined, and/or copied for a fee, at the NRC's Public Document room, 
located at One White Flint North, 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, http\\www.nrc.gov. If you do not have access to ADAMS or 
if there are problems in accessing the documents located in ADAMS, 
contact the NRC Public Document Room (PDR) Reference staff at 1-800-
397-4209, 301-415-4737 or by email to [email protected].

    For the Nuclear Regulatory Commission.

    Dated at Rockville, Maryland, this 21st day of November 2001.
Guy S. Vissing,
Project Manager, Section 1, Project Directorate I, Division of 
Licensing Project Management, Office of Nuclear Reactor Regulation.
[FR Doc. 01-29585 Filed 11-27-01; 8:45 am]
BILLING CODE 7590-01-P