ML20212G538
| ML20212G538 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 10/28/1997 |
| From: | Hebdon F NRC (Affiliation Not Assigned) |
| To: | |
| Shared Package | |
| ML20212G543 | List: |
| References | |
| NUDOCS 9711060221 | |
| Download: ML20212G538 (12) | |
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2*4 UNITED STATES g
j NUCLEAR REGULATORY COMMISSION 2
WASHINGTON, D.C. 20066-0001 o%...../
FLORIDA POWER CORPORATION CITY OF A_LACHUA CITY OF BUSHNELL CITY OF GA' NESVil'_E CITY OF K SSIMME E CITY OF LEESBURG CITY OF NEW SMYRNA BEACH AND UTILITIES COMMISSION. CITY OF NEW SMYRNA BEACH CITY OF OCALA QR.LANDO UTILITIES COMMIS$10N AND CITY OF ORLANDO SEMINOLE ELECTRIC COOPERATIVE. INC.
CITY OF TALLAHASSEE DOCKET NO. 50-302 CRYSTAL RIVER UNIT 3 NUCLEAR GENERATING PLANT AMENDMENT TO FACILITLOPERATING LICENSE Amendment No.158 License No. DPR-72 1.
The Nuclear Regulatory Commission (the Commission) has found that:
A.
The application for amendment by Florida Power Corporation, et al.
(the licensees) dated March 27, as supplemented April 3. May 1. and August 20, 1997, complies with the standards and recuirements of the Atomic Energy Act of 1954, as amended (the Act), anc the Commission's rules and regulations set forth in 10 CFR Chapter I:
B.
The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission:
C.
There is reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations:
D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public: and E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
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2.
'Accordingly, the license is amended by changes to the Technical 4
Specifications as indicated in the attachment to this' license amendment.
i, and paragraph 2.C.(2) of Facility Operating License No.-DPR-72 is hereby amended to read as follows:
f Technical Soecifications l
The Technical Specifications contained in A)pendices A and B. as revised through Amendment No.158. are here]y incoraorated in the
' license.
Florida Power Corporation shall operate t1e facility in l'
accordance with the Technical Specifications.
3.
This license amendment is effective as of its date of issuance and shall be implemented within 30 days.
FOR THE NUCLEAR REGULATORY COMMISSIW i
M*
Frederick J. Hebden. Director Project Directorate 11-3 Division of Reactor Projects - I/II Office-of Nuclear Reactor Regulaticn
Attachment:
Changes to the Technical Specifications-Date of Issuance: October 28, 1997 e
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ATTACHMENT TO LICENSE AMENDMENT NO.158 -
FACILITY OPERATING' LICENSE NO. DPR-72 DOCKET NO. 50-302 Replace the followin the attached pages. g sages of the Appendix;"A" Technical Specifications with-T1e revised pages are identified by amendment number and contain vertical lines indicating the area of change.
The corresponding overleaf pages are also provided to maintain document completeness.
Remove -
Insert 3.4 22 3.4-22 B3.4-54 B3.4-54 B3.4-55 83.4-55 5.0 14 5.0-14 5.0-14A 5.0-16 5.'0-16 5.0-16A 5.0-17 5.0-17 5.0 29 5.0-29 5.0 29A 5.0-29A
i RCS Operational LEAKAGE 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 RCS Operational LEAKAGE 1
LCO 3.4.12 RCS operational LEAKAGE shall be limited to:
I a.
No pressure boundary LEAKAGE; b.
I gpm unider.tified LEAKAGE; c.
10 gpm identified LEAKAGE; and d.
150 gpd of primary-to secondary LEAKAGE through any one steam generator (OTSG).
4 Two OTSGs shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, 3, and 4.
ACTIONS 4
CONDITION REQUIRED ACTION COMPLETION TIME a
A.
RCS LEAKAGE not within A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limits for reasons within limits, other than pressure boundary LEAKAGE.
B.
Required Action and B.1 Be in MODE 3.
6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
ANQ QB B.2 Be in MODE 5.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Pressure boundary LEAKAGE exists.
Crystal River Unit 3 3.4-22 Amendment No.158
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RCS Operational LEAKAGE B 3.4.12 BASES APPLICABLE The TSAR (Ref. 3) analysis for steem generator tube rupture l
SAFETY ANALYSES (SGTR) assumes the contaminated secondary fluid is only (continued) briefly released via safety valves and the majority is steamed to the condenser..The 1 gpm primary to secondary LEAKAGE is relatively inconsequential in terms of offsite dose.
The FSAR steam line break (SLB) analysis (Ref. 4) is more limiting for site radiation releases. The safety analysis for the SLB accident assumes 1 gpm primary to secondary LEAKAGE in one generator as an initial condition.
The dose consequences resulting from the SLB accident meet the acceptance criteria defined in 10 CFR 100.
RCS operational LEAKAGE satisfies criterion 2 of the NRC Policy Statement, LC0 RCS operational LEAKAGE shall be limited to:
a.
Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material deterioration.
LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE.
Violation of this LC0 could result in continued degradation of the reactor coolant 3ressure boundary l
(RCPB).
LEAKAGE past seals and gas (ets is not pressure boundary LEAKAGE.
b.
Oro gallon per minute (gpm) of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment atmosphere and sump level monitoring equipment can detect within a reasonable time period.
Violation of this LCO could result in continued degradation of the RCPB, if the LEAKAGE is from the l
pressure boundary.
(continued)
Crystal River Unit 3 8 3.4-54 Amendment No.158
- =. - -.
RCS Operational LEAKAGE 8 3.4.12 BASES.
LC0 c.
Identified LEAKAGE Up to 10 gpm of identified LEAXAGE is considered allowable because_ LEAKAGE is from known sources that do not interfere with the detection of unidentified LEAKAGE and is well within the capability of the RCS makeup system.
Identified LEAKAGE includes LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal leakoff (a normal function not considered LEAKAGE).
Violation of this LCO could result in continued 4
degradation of a component or system.
d.
Primary to Secondary LEAKAGE throuah All Steam Generators (OTSGs) 4 I
This LEAKAGE limit is estaolished to ensure that tubes initially leaking during no. mal operation do not contribute excessively to total leakage during postulated accident conditions. The 150 gpd limit is a conservative limit which is consistent with the operational leakage limit specified in NRC Generic Letter 95-05 for plants implementing Alternate Repair Criteria.
CR-3 has elected to voluntarily adopt this conservative limit to ensure plant shutdown in a timely manner in response to detection of primary to secondary LEAKAGE.
Primary to secondary LEAKAGE must be included in the total allowable limit for identified LEAKAGE.
Two OTSGs are also required to be OPERABLE. This requirement is met by satisfying the augmented inservice inspection requirements of the Steam Generator Tube Surveillance Prograra (2pecification 5.6.2.10).
(continued)
Crystal River Unit 3 B 3.4-55 Amendment No.158
i Procedures, Programs and Manuals 5.6 5.6 Procedures, Programs and Manuals 5.6.2.10 OTSG Tube Surveillance Program (continued) in the specific area of an OTSG are inspected with the inspection result classification and the corresponding action required as specified in Table 5.6.2-3.
No credit will be taken for tnese tubes in meeting minimum sample size requirements. Degraded or defective tubes found in these areas will not be considered in determining the inspection results category as long as the mode of degradation is unique to that area and not random in nature, e.
Inservice tubes with pit-like IGA indications in the first span of the B OTSG, identified in the OTSG Inservice InsSection Surveillance Procedure, must be inspected witi bobbin and Motorized Rotating Pancake Coil (MRPC) eddy current techniques from the lower tube sheet secondary face to the bottom of the first tube support plate during each inservice inspection of the B OTSG.
No credit is to be taken for this inspection in meeting minimum sample size requirements for the random inspection. Defective tubes found during this inspection are to be plugged or sleeved.
Degraded o1 defective tubes found during this inspection are not to be considered in determining the inspection results category for the random inspection, unless the degradatiun mechanism identified is a mechanism other than pit-like IGA.
4 (continued)
Crystal River Unit 3 5.0-14 Amendment No.158
Procedures, Programs and Manuals 5.6 L
5.6 Procedures, Programs and Manuals 5.6.2.10 OTSG Tube Survalliance Progra, (continued)
The results of each bobbin coil sample inspection shall be classified into one of the following three categories:
..............................N0TE In all inspections, previously degraded tubes whose degradation hasnotbeenspannedbyatieevemustexhibitsignificant(>10%)
further wall penetration: to be included in the below percentage calculations.
Cateaory Insoection Results C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are
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defective.
C2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.
C3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.
(continued)
Crystal River Unit 3 5.0-14A Amendment No.158
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Procedures, Programs and Manuals 5.6 5.6 Procedures, Programs and Manuals 5.6.2.10 OTSG Tube Surveillance Program (continued) 4.
Acceptance criteria:
a.
heabulary as used in this Specification:
1.
Tubing or Tube means that portion of the tube or sleeve which forms the primary system to secondary system pr:ssure boundary.
2.
Imperfection means an exception to the dimensions, finish or contour of a tube from that required by fabrication drawings or specifications.
Eddy-current testing indications below 20% of the nominal tube wall thickness, if detectable, may be
,:onsidered as imperfections.
3.
Degradation means a service induced cracking, wastage, wear, or general corrosion occurring on either inside or outside of a tube.
4.
Degraded Tube means a tube containing imperfections 2 20% of the nominal wall thickness caused by degradation except where 11 such degradation h e been spanned by the installation of a sleeve.
5.
% Degradu en m.ns the percentage of the tube wall thirbar s Lrfected or removed by degradation.
6.
Defect means an imperfection of such severity that it exceeds the plugging / sleeving limit except where the imperfection has been spanned by the installation of a sleeve. A tube containing a defect in its pressure boundary is defective. Any tube which does not permit the )assage of the eddy-current inspection probe siall be deemed a defective tube.
7.
Pit-like Intergranular Attack (IGA) indication means a bobbin co;l indication confirmed by Motorized Rotating Pancake Coil (MRPC) or other qu:lified inspection techniques to have a volumetric, pit-lik; morphology characteristic of IGA.
(continued)
Crystal River Unit 3 5.0-16 Amendment No.158 I
1
Procedures Programs and Manuals 5.6 5.6 Procedures, Programs and Manuals 5.6.2.10 OTSG Tube Surveillance Program (continued) 8.
Plugging / Sleeving Limit means the extent of degradation beyond which the tube shall be restored to serviceability by the installation of a sleeve or removed from service because it may become unserviceable prior to the next inspection and is equal to 40% of the nominal tube or sleeve wall thickness. No more than five thousand sleeves may be installed in each OTSG.
9.
Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss of-coolant accident, or a main steam line or feedwater line break, as specified in 5.6.2.10.3.c. above.
10.
Tube inspection means an inspection of the entire OTSG tube as far as possible, b.
The OTSG shall be determined OPERABLE after completing the corresponding actions (plug or sleeve all tubes exceeding the pluggir.9/ sleeving limit and all tubes containing through wall cracks) required by Table 5.6.2 2 (and Table 5.6.2-3 if the provisions of Specification 5.6.2.10.2.d are utilized). Defective-tubes may be re) aired in accordance with the B&W process (or met 1od) equivalent to the method described in report BAW-2120P.
5.6.2 11 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit steam generator tube degradation and low pressure turbine disc stress corresion cracking.
The program shall include:
a.
Identification of a sampling schedule for the critical variables and control points for these variables; b.
Identification of the procedures used to measure the values of the critical variables; (continued)
Crystal River Unit 3 5.0 17 Amendment No.iS8 1
Reporting Requirements 5.7 5.7 Reporting Requirements 5.7.2 Special Reports (continued)
The following Special Reports shall be submitted:
a.
When a Special Report is required by Condition B or F of LCO 3.3.17. " Post Accident Monitoring (PAM) d within the instrumentation," a report shall be submitte following 14 days. The report shall outline the preplanned alternate me.thod of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channLis )f the Function to OPEPABLE status, b.
Any abnormal degradation of the containment structure detected during the tests required by the Contkinment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (es)ecially at tendon anchorages), the inspection procedures, tie tolerances on cracking, and the cortective action taken.
c.
Following each inservice ins)ection of steam generator prior)toascensionintoMODE4: tubes, the NRC shall ao notified of the following (OTSG 1.
Number of tubes plugged and sleeved 2.
Crack-like indications in the first span 3.
An assessment of growth in the first span indications, and 4.
Results of in situ pressure testing, if performed.
The complete results of the OTSG tube inservice inspection shall be submitted to the NRC within 90 days following the completion of the inspection.
The report shall include:
1.
Number and extent of tubes inspected, 2.
Location and percent of wall thickness penetration for each indication of an imperfection, Location, bobbin coil am 3.
circumferential extent (plitude, and axial and if determined) for each first span IGA indication, and 4.
Identification of tubes plugged and tubes sleeved.
(continued)
Crystal River Unit 3 5.0 29 Amendment No.158
Reporting Requirements 5.7 i
5.7 Reporting Requirements 5.7.2 SpecialReports(continued)
Results of OTSG tube inspections that fall into Category C 3 shall be reported to the NRC prior to resumption of plant operation.
This report shall provide a description of investigations conducted to deterraine cause of the tube degradation and corrective measures taken to prevent recurrence.
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Crystal. River Unit 3 5.0 29A Amendment No.158
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