ML20070K222

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Proposed Tech Specs,Relocating Fire Protection Requirements to Administrative Procedure.Draft mark-up Administrative Procedure AP-01.04, Tech Spec Related Requirements,Lists & Tables Included
ML20070K222
Person / Time
Site: FitzPatrick Constellation icon.png
Issue date: 07/21/1994
From:
POWER AUTHORITY OF THE STATE OF NEW YORK (NEW YORK
To:
Shared Package
ML20070K170 List:
References
NUDOCS 9407260141
Download: ML20070K222 (101)
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Text

Attachment I to JPN-94-033 P_B_0EOSEDJECHNICALSEECIELCAIlON_QHANGES (J PTS-93-020) l I

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New York Power Authority JAMES A. FITZPATRICK NUCLEAR POWER PLANT Docket No. 50-333 DPR-59 9407260141 940721 PDR ADOCK 05000333 P PDR s

JAFNPP IABtJLOF COMEtES_(Cont'd) l Eage D. Emergency Service Water System 240 E. Intake Deicing Heaters 242 DELETED 244a l 5.0 Design Features 245 5.1 Site 245 5.2 Reactor 245 5.3 Reactor Pressure Vessel 245 5.4 Containment 245 5.5 Fuel Storage 245 5.6 Seismic Design 246 6.0 Administrative Controls 247 6.1 Responsibility 247 6.2 Organization 247 6.2.1 Facility Management and Technical Support 247 6.2.2 Plant Staff 247a 6.3 Plant Staff Qualifications 248 6.4 Retraining and Replacement Training 248 6.5 Review and Audit 248 6.5.1 Plant Operating Review Committee (PORC) 248a 6.5.2 Safety Review Committee (SRC) 250 6.6 Reportable Event Action 253 6.7 Safety Limit Violation 253 6.8 Procedures 253 6.9 Reporting Requirements 254a l 6.10 Record Retention 254g l 6.11 Radiation Protection Program 255 6.12 Industrial Security Program 258 6.13 Emergency Plan 258 6.14 Fire Protection Program 258 6.15 Environmental Qualification 258a Amendment No. 7722-32rB4 737 7 93r440-180 7407, iii

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JAFNPP LISI_OF TABLES Iab!f: Iit!a Eage I 1

4.2-8 Minimum Test and Calibration Frequency for Accident Monitoring 86 l Instrumentation 4.6-1 Snubber Visual Inspection Interval 161 4.6-2 Minimum Test and Calibration Frequency for Drywell Continuous 162a Atmosphere Radioactivity Monitoring System 4.7-1 (DELETED) 210 4.7-2 Exception to Type C Tests 211 3.12-1 (DELETED) 244a 3.12-2 (DELETED) 244a 3.12-3 (DELETED) 244a 4.12-1 (DELETED) 244a 4.12-2 (DELETED) 244a 4.12-3 (DELETED) 244a 6.2-1 Minimum Shift Manning Requirements 260a 6.10-1 Component Cyclic or Transient Limits 261 Amendment No. 20-22-92-444-180,-t-34-150-478-4 80,-1817240, vi

JAFNPP 1.0 (cont'd)

U. Thermal Parameters V. Ele _cLrically_Risarmed Control Rod

1. Minimum critical power ratio (MCPR)- Minimum value To disarm a rod drive electrically, the four amphenol type of the ratio of that power in a fuel assembly which is plug connectors are removed from the drive insert and calculated to cause some point in that fuel assembly to withdrawal solenoids rendering the rod incapable of experience boiling transition to the actual assembly withdrawal. This procedure is equivalent to valving out the operating power for all fuel assemblies in the core. drive and is preferred. Electrical disarming does not eliminate position indication.
2. Fraction of Umiting Power Density - The ratio of the linear heat generation rate (LHGR) existing at a given W. Deleted l location to the design LHGR.

X. Staggered Test Basis

3. Maximum Fraction of Umiting Power Density - The Maximum Fraction of Limiting Power Density (MFLPD) A Staggered Test Basis shall consist of:

is the highest value existing in the core of the Fraction of Limiting Power Density (FLPD). a. A test schedule for "n" systems, subsystems, trains or other designated components obtained

4. Transition Boiling - Transition boiling means the boiling by dividing the specified test interval into "n" region between nucleate and film boiling. Transition equal subintervals.

boiling is the region in which both nucleate and film boiling occur intermittently with neither type being b. The testing of one system, subsystem, train or completely stable. Other designated component at the beginning of each subintental.

Y. Rated Recirculation Flow That drive flow which produces a core flow of 77.0 x 10' lb/hr.

Amendment No. 45-64-72-74-400.134, 162-188, 6

JAFNPP Pages 244a - 244w DELETED l Amendment No. 347 -80, 13 d , 135,1A2,164d76,17,18&r490d &tr206, 244a

JAFNPP

2. An SRO or an SRO with a license limited to fuel handling shall directly supervise all Core Alterations. This person shall have no other duties during this time;
3. DELETED l
4. In the event of illness or unexpected absence, up to two (2) hours is allowed to restore the shift crew to the minimum complement. l S. The Operations Manager, Assistant Operations Manager, Shift Supervisor and Assistant Shift Supervisor shall hold a SRO license and the Senior Nuclear Operator and the Nuclear Control Operator shall hold a RO license or an SRO license. j
6. Administrative procedures shall be developed and implemented to limit the working hours of unit staff who perform safety-related functions; e.g., senior reactor operators, health physicists, auxiliary operators, and maintenance personnel who are working on safety-related systems.

Adequate shift coverage shall be maintained without routine heavy use of overtime. The objective shall be to have operating personnel work a normal 8-hour day, 40-hour week while the plant is operating.

However, in the event that unforeseen problems require substantial amounts of overtime to be used or during extended periods of shutdown for refueling, major maintenance or major modifications, on a temporary basis, the following guidelines shall be follo'Ned:

a. An individual should not be permitted to work more than 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> straight, excluding shift turnover time.
b. An individual should not be permitted to work more than 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> in any 24-hour period, nor more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> in any 48-hour period, nor more than 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> in any seven day period, all excluding shift tumover time,
c. A break of at least eight hours should be allowed between work periods, including shift tumover time.
d. Except during extended shutdown periods, the use of overtime should be considered on an individual basis and not for the entire staff on a shift.

Any deviation from the above guidelines shah be authorized by the Resident Manager or the General Manager - Operations, or higher levels of management, in accordance with established procedures and with documentation of the basis for granting the deviation.

Controls shall be included in the procedures such that individual overtime shall be reviewed monthly by the Resident Manager or his designee to assure that excessive hours have not been assigned. Routine deviation from the above guidelines is not authorized.

Amendment No. 49,-144r-430,-437A76-190, 247a

JAFNPP 6.3 PLANT STAFF QUALIFICATIONS 6.3.1 The minimum qualifications with regard to educational background and experience for plant staff positions shown in FSAR Figure 13.2-7 shall meet or exceed the minimum qualifications of ANSI N18.11971 for comparable positions; except for the Radiological and Environmental Services Manager who shall meet or exceed the qualifications of Regulatory Guide 1.8, September 1975.

6.3.2 The Shift Technical Advisor (STA) shall meet or exceed the minimum requirements of either Option 1 (Combined SRO/STA Position) or Option 2 (Continued use of STA Position), as defined in the Commission Policy Statement on Engineering Expertise on Shift, published in the October 28,1985 Federal Register (50 FR 43621). When invoking Option 1, the STA role may be filled by the Shift Supervisor or Assistant Shift Supervisor. (1) 6.3.3 Any deviations will be justified to the NRC prior to an individual's filling of one of these positions.

NOTE:

(1) The 13 individuals who hold SRO iicenses, and have completed the FitzPatrick Advanced Technical Training Program prior to the issuance of License Amendment 111, shall be considered qualified as dual-role SRO/ STAS.

6.4 RETRAINING AND REPLACEMENT TRAjMNG A training program shall be maintained under the direction of the Training Manager to assure overall proficiency of the plant staff organization. It shall consist of both retraining and replacement training and shall meet or exceed the minimum requirements of Section 5.5 of ANSI N18.1-1971.

The retraining program shall not exceed periods two years in length with a curriculum designed to meet or exceed the requalification requirements of 10 CFR 55.59. l 6.5 BEYJEVJLAND AUDIT Two separate groups for plant operations have been constituted. One of these, the Plant Operating Review Committee (PORC), is an onsite review group. The other is an independent review and audit group, the offsite Safety Review Committee (SRC).

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Amendment No. 22AL47 577 99,-1447 434r4377478r490, 248

JAFNPP I (B) Altemates Alternative members shall be appointed in writing by the PORC Chairman to serve on a temporary basis; however, no more than two attemates shall participate in PORC activities at any one time. J (C) Meeting Frequency Meetings will be called by the Chairman as the occasions for review or investigation arise.

Meetings will be no less frequent than once a month. l (D) Quorum A quorum of the PORC shall consist of the Chairman or one of three Vice-Chairmen and five members including designated allemates. Vice-Chairmen may act as members when not acting as Chairman.

(E) Responsibilities

1. Review plant procedures, and changes thereto, required by Specification 6.8.
2. Review proposed tests and experiments that affect nuclear safety.
3. Review proposed changes to the Operating License and Technical Specifications.
4. Review proposed changes or modifications to plant systems or equipment that affect nuclear safety.
5. Investigate violations of the Technical Specifications and prepare and forward a report covering evaluation and recommendations to prevent recurrence to the Resident Manager, who will forward the report to the Manager - Nuclear Operations and to the Chairman of the Safety Review Committee.
6. Review plant operations to detect potential safety hazards.
7. Review the Security Plan (including the Safeguards Contingency Plan) and implementing procedures annually.
8. Review the Emergency Plan and implementing procedures annually.

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9. Perform special review and/or investigations at the request of the Resident Manager. I
10. Review of all reportable events.
11. Review the Offsite Dose Calculation Manual (ODCM) and implementing procedures at least once per 24 months.

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12. Review the Process Control Program (PCP) at least once per 24 months. l
13. Review the FitzPatrick Fire Protection Program and implementing procedures and changes thereto.

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! Amendment No. 22-67r04r178, '

249

^l JAFNPP 1

(F) Authority The PORC shall function to advise the Resident Manager on all matters related to nuclear safety and environmental operations. The PORC shall recommend approval or i disapproval to the Resident Manager of those items considered in 6.51E (1) through j (4) and determine if items considered in 6.51E (1) through (5) constitute unreviewed - ,

safety questions, as defined in 10 CFR 50.59.  ;

1 in the event of a disagreement between the PORC and the Resident Manager, the  ;

Chairman of the SRC and the Executive Vice President-Nuclear Generation, or their designated alternates, shall be notified within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and written notification provided i on the next business day; however, the Resident Manager shall have responsibility for resolution of such disagreement pursuant to Section 6.1.

l (G) Records Minutes of all meetings of the PORC shall be recorded and numbered. Copies will be retained in file. Copies will be forwarded to the Chairman of the SRC and the Executive Vice President-Nuclear Generation.

(H) Procedures Conduct of the PORC and the mechanism for implementation of its responsibilities and' l authority are defined in the pertinent Administrative Procedures.

l 6.5.2 SAFETY REVIEW COMMITTEE (SRC)

FUNCTION 6.5.2.1 The SRC shall function to provide independent review and audit of designated activities in the areas of: ,

a. Nuclear power plant operations
b. Nuclear engineering
c. Chemistry and radiochemistry
d. Metallurgy
e. Instrumentation and control i

P Amendment No. 50, 70, 03, 04, H0, 250

JAFNPP (B) SEECJAL REPOHIS

1. Fifteen copies of the Evaluation Report of the results of the first five years of performance of the non-destructive inspection listed in Table 4.6-1 of Technical Specifications 4.6.F, Structural Integrity, relating to the FitzPatrick in-sewice inspection program shall be submitted to the NRC, Director of Operating Reactors, within three months of the completion of the fifth year of the program.
2. DELETED l 6.10 BEC_QBD RETENTION (A) The following records shall be retained for at least five years:
1. Records and logs of facility operation covering time intervals at each power level.
2. Records and logs of principal maintenance activities, inspections, repair and replacement of principal items of equipment related to nuclear safety.
3. All Reportable Events.
4. Records of suweillance activities, inspections and calibrations required by these Technical Specifications.
5. Records of reactor tests and experiments.
6. Records of changes made to Operating Procedures.
7. Records of radioactive shipments.
8. Records of sealed source leak tests and results.
9. Records of annual physical inventory of all source material of record.

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Amendment No. 34H40-476, 7

254g

Attachment 11 to JPN-94-033 EROP_01ED_Off RAllNG_LIC ENSE_CHAJG ES (J PTS-93-020)

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New York Power Authority JAMES A. FITZPATRICK NUCLEAR POWER PLANT Docket No. 50-333 DPR-59

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(3) Fire Protection The licensee shall inclement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility and as approved in the SER dated g November 20, 1972, the SER Supplement No. 1 dated February 1, 1973, the SER Supplement No. 2 dated October 4, 1974, the SER dated August 1, 1979, the SER Z Supplement dated October 3, 1980, the SER Supplement dated February 13, 1981 and the NRC Letter dated February 24, 1981 subject to the following provision: w N

The licensee may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

(4) Systems Intearity The licensee shall implement a program to reduce leakage from the syctene outside containment that would or could contain highly radioactive fluids during a serious transient or ar cident to as low as practical levels. This program shall include the following:

1. Provisions establishing maintenance and periodic visual inspection requirements, and
2. Leak test requirements for the systems at a g frequency not to exceed operating cycle _ intervals.

(5) Iodine Monitorina X The licensee shall implement a program which will U ensure the capability to accurately determine the g airborne iodine concentration in areas vital to the mitigation of or recovery from an accident. This program shall include the following:

1. Training of personnel,
2. Procedures for monitoring, and
3. Provisions for maintenance of sampling and analysis equipment.

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(3) Pursuant to the Act and 10 CFR. Parts 30, 40, and 70, to receive, possess, and use, at any time, any byproduct, source, and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use, at any time, any byproduct, source and special nuclear material without restriction k to chemical or physical form, for sample analysis or instrument calibration; or associated with radioactive g apparatus, components or tools. $

4 (5) Pursuant to the Act and 10 CFR Parts 30 and 70, to g possess, but not separate, such byproduct and special N nuclear materials as may be produced by the operation of the facility.

C. The license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1) Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2436 megawatts (thermal).

(2) Technical Soecifications The Technical Specifications contained in Appendices A

  • are hereby and B, as revised through Amendment No. ,

incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

  • Each amendment updates this paragraph to indicate the latest amendment to the License.

Attachment lli to JPN-94-033 SAFETY EVALUATION FOR PROPOSED TECHNICAL SPECIFICATION AND DPJEBAllMO_LICliNSE_CHARGESJJEIS-93-020)

1. EURP_0_SE OF THE PROPOSED _ CHANGES The purpose of these proposed changes is to move technical requirements for fire protection equipment and components from the FitzPatrick Technical Specifications to a New York Power Authority administrative procedure in accordance with the guidance in NRC Generic Letters 86-10 and 88-12. Using the guidance in these GLs, this proposed change:
1. replaces the existing license condition with the standard license condition for a Fire Protection Program,
2. removes requirements for fire protection systems from the Technical Specifications,
3. removes fire brigade staffing requirements from the Technical Specifications, and
4. adds administrative controls to the Technical Specifications that are consistent with those for other programs required by license condition.

The proposal deviates from the material presently in the FitzPatrick Technical Specifications only where necessary to correct statements that would be incorrect if relocated, or are not applicable in an administrative procedure. No changes have been proposed to the operating, sunteillance or administrative requirements except as noted above.

Generic _ Letter 86-10 Nuclear Regulatory Comrnission (NRC) Generic Letter 86-10 (Reference 1) Section F,

" Addition of Fire Protection Program into UFSAR," describes several problems for licensees and NRC inspectors in identifying the operative and enforceable fire protection requirements at each licensed facility. The NRC has concluded that the best way to resolve these problems, is to incorporate the fire protection program and major commitments, including the fire hazards analysis, by reference into the Updated Final Safety Analysis Report (UFSAR) for the facility. In so doing, the plant features associated with the fire protection program would be on a consistent status with other plant features described in the UFSAR. In addition, the provisions of 10 CFR 50.59 will apply for changes made in the Fire Protection Program to assure that any changes would not involve an unreviewed safety question.

Generic _ Letter 88-12 Generic Letter 88-12 (Reference 2) provided further guidance for the preparation of the license amendment to implement Generic Letter 86-10. Generic Letter 88-12 suggests that the amendment remove the fire protection requirements from Technical Specification in four major areas: fire detection systems, fire suppression systems, fire barriers, and fire brigade staffing requirements.

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Attachment 111 to JPN-94-033 I

. SAFETY EVALUATION j Page 2 of 11

11. DESGBlPlL0tLOE_THE PROPOSED _ CHANGER This section is divided into three parts; one part for each of the three documents associated with these proposed changes. Part (1) is a description of the proposed I changes to the Technical Specifications and the Operating License (OL). Part (2) is a l description of the proposed changes to the UFSAR and Part (3) describes the proposed changes to FitzPatrick Administrative Procedure AP-01.04. Minor changes in format,  ;

such as type font, margins or hyphenation, are not described in this submittal. This type of change is typographical in nature and does not affect the content of the either the Technical Specifications or the UFSAR.

(1) DESCRIPTION OF THE PROPOSED CHANGES TO THE TECHNICAL SPEC 1ELGallONS AND THE OPERATING LICENSE This amendment proposes three changes to the Technical Specifications and Operating License:

G Delete fire protection requirements from the Technical Specifications, e Add item 13 to Specification 6.5.E of the Technical Specifications which designates the Plant Operating Review Committee with responsibility for reviewing the fire protection program and implementing procedures and changes thereto, and e Replace Operating License Paragraph 2.C(3) with the standard fire protection license condition provided in NRC Generic Letter 86-10.

Technical Soecifications Page iii. Table of Contents Replace the following:

"3.12 Fire Protection Systems 4.12 244a A. High Pressure Water Fire Protection System A. 244a B. Water Spray and Sprinkler Systems ' B. 244e C. Carbon Dioxide Systems . C. 244e D. Manual Fire Hose Stations D. 244f E. Fire Protection Systems Smoke and Heat Detectors E. 244g F. Fire Barrier Penetration Seals F. 244g" with

" DELETED 244a"

Attachment 111 to JPN-94-033 SAFETY EVALUATION Page 3 of 11 TechnicaLSpecifications Page_vk_ List of Tables Replace the following:

"3.12-1 Water Spray / Sprinkler Protected Areas 244j 3.12-2 Carbon Dioxide Protected Areas 244k 3.12-3 Manual Fire Hose Stations 2441 4.12-1 Water Spray / Sprinkler Protected Tests 244q 4.12-2 Carbon Dioxide Protected Tests 244r 4.12-3 Manual Fire Hose Station Tests 244s" with "3.12-1 (DELETED) 244a 3.12-2 (DELETED) 244a 3.12-3 (DELETED) 244a 4.12-1 (DELETED) 244a 4.12-2 (DELETED) 244a 4.12-3 (DELETED) 244a" IechnicalSpecifications. Page 6 Replace the following:

"W. High PressurfLWaleLFire Protection System The High Pressure Water Fire Protection System consists of: a water source and pumps; and distribution system piping with associated post indicator valves (isolation valves). Such valves include the yard hydrant curb valves and the first valve ahead of the water flow alarm device on each sprinkler or water spray subsystem."

with "W. Deleted" Iechnical Specificatio0S1_Eage1244sLth_tougt1144w Replace pages 244a through 244w with a new page 244a, which will state:

"Pages 244a-244w DELETED"

Attachment lil to JPN-94-033 SAFETY EVALUATION Page 4 of 11 Iect)nical Specifications. Pagel4Za Replace the text of Section 6.2.2.3 ["A fire Brigade . . fire emergency;"] with:

" DELETED."

IeshnicaLSpecificationsJ' age 247a Delete the phrase "or fire brigade" from Section 6.2.2.4.

IechnicaLSpecifications. Page_2L43 Delete the last two sentences from the second paragraph of Section 6.4 ["In addition, !

. March 17,1978."].

I Technical Specifisations. Page 249 l

Relocate Specifications 6.5.1.E.8 through 6.5.1.E.12 from page 250 to page 249. i 1

Add item 13 to Section 6.5.1.E which will state: l "13. Review of the FitzPatrick Fire Protection Program and implementing procedures and changes thereto."

InchoicaLSpecifications3_ age _250 Insert a change bar to indicate that Specifications 6.5.1.E.8 through 6.5.1.E.12 were relocated to page 249 as described above.

InchalcaLSpacificationsf_ age.2549 Replace the text of item 2 of Section 6.9(B) ["Special reports . . 3.12.F.2."] with:

" DELETED."

s a . ___ _ __ __ _ _ - _

~ _ _ _ _ . ._ __ ,_ _ _ _ , . _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ . .

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1 Attachment 111 to JPN-94-033 SAFETY EVALUATION Page 5 of 11 Operating License. Pages 3 and 3a Replace the text of Paragraph 2.C(3) ["The licensee . . . January 1,1980."] with:

"The licensee shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report j for the facility and as approved in the SER dated November 20,1972, the j SER Supplement No.1 dated February 1,1973, the SER Supplement No. 2 dated October 4,1974, the SER dated August 1,1979, the SER Supplement dated October 3,1980, the SER Supplement dated February 13,1981 and the NRC Letter dated February 24,1981 subject to the following provision:

The licensee may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not  ;

adversely affect the ability to achieve and maintain safe shutdown in the l event of a fire." j (2) DESCRIPTION OF THE PROPOSED CHANGES TO THE UFSAR j

Paragraphs discussing the Fire Protection Program Plan (as defined in 10 CFR 50.48),

the Fire Hazards Analysis and the Fire Protection Quality Assurance Program will be  !

added to the UFSAR in Sections 9.8.5 Fire Protection Program" and 9.8.6 " Fire )

Protection Quality Assurance Program." These changes willincorporate these three documents by reference.

Section 9.8.5 will replace a section previously titled " Administrative Control." Section 9.8.6 was previously titled " Fire Protection."

The above proposed changes will be submitted with the 1995 UFSAR Amendment.

Attachment 111 to JPN-94-033 SAFETY EVALUATION Page 6 of 11 (3) DESCRIPTION OF THE PROPOSED CH_ANGES TO FITZPATRICK ADMINISTRATIVE EHQCED1)RE AP-01.04 FitzPatrick Administrative Procedure AP-01.04, Attachment 2 (" Fire Protection Requirements") will contain the fire protection Limited Conditions for Operation, Surveillance Requirements and Bases currently contained in the Technical Specifications. With seven exceptions, the Technical Specification General Requirements (Specifications 3.0 and 4.0) text will be duplicated in Attachment 2 and the Technical Specification Fire Protection Requirements (Specifications 3.12 and 4.12) text will be relocated to Attachment 2, without change. Six of the seven exception are administrative; one change affects reporting requirements for fire protection equipment and components.

Specifically, these exceptions are:

9 A sentence which discusses 10 CFR 50.73(a)(2)(i)(B) in the Bases for Technical Specification 4.0.C has been deleted. This CFR citation deals with submitting Licensee Event Reports when Technical Specification requirements are not followed. This part of Title 10 is not applicable to the Administrative Procedure and will not be included in the Bases in the Administrative Procedure.

9 The six remaining exceptions are administrative.

The phrase " pursuant to Specification 6.9.B . . ." in Technical Specification 3.12.F.2, is not relevant to the Administrative Procedure since Technical Specification 6.9.B.2 is being deleted, thus the phrase will not be in the Administrative Procedure; The last sentence of Technical Specification 6.4 specifies an implementation date (March 17,1978) for the fire brigade training. Since fire brigade training has been implemented, the date will not be duplicated in the Administrative Procedure; Replacing the term "Umited Condition for Operation" with " Technical Requirement;"

Replacing the terms " Technical Specification" or " Specification" with " Technical Requirement", " Surveillance Requirement" or " Administrative Requirement" as appropriate; Fleplacing Technical Specification section numbering and cross-references with appropriate Administrative Procedure section numbering and cross-references, Table 1 provides a Technical Specification to Administrative Procedure cross-reference; and Correcting an erroneous reference in Technical Specification 3.12.A.1.c. This Technical Specification incorrectly references Technical Specification 6.9.1.A, the correct reference is 6.9.A which will be reflected in the Administrative Procedure.

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k Attachment lll to JPN-94-033 SAFETY EVALUATION Page 7 of 11 lil, SAFETY IMPLICAIf0NS QE_IliE PROPOSELD_C11ANGES There are no safety implications associated with these changes because:

e No Fire Protection Requirements have been deleted (the same Limited Conditions for Operation and the same Surveillance Requirements are still ,

in effect),

e The effectiveness of the program will be assured by the revised Ucense Condition which is the standard license condition provided in Generic Letter 86-10, e The Administrative Procedure and PORC review of the Administrative Procedure as required by item 13 to Technical Specification 6.5.1.E assure no loss of effectiveness, e The provisions of 10 CFR 50.59 apply to changes made in the Fire .,

Protection Program to assure that any changes do not involve an  !

unreviewed safety question, and '

i e The exceptions discussed in ll(3) above are editorial in nature, and no  !

reduction has been made to the technical content by these editorial  ;

changes.

Operating limitations will continue to be imposed, and required surveillances will continue to be performed in accordance with written procedures and instructions auditable by the NRC. Fire protection program requirements remain an integral part of James A.

FitzPatrick Nuclear Power Plant operation, regardless of location.

Although future proposed changes to the fire protection program elements previously 1 located in the Technical Specifications will no longer be controlled by 10 CFR 50.36, proposed changes to the Fire Protection requirements relocated to an administrative procedure will be evaluated by the License Condition,10 CFR 50.59 and plant procedures.

This proposed amendment relocates the Fire Protection Program elements from the Technical Specifications to the Administrative Procedure, and includes additional references to the existing program in the UFSAR. Compliance with fire protection requirements will be assured by maintaining these requirements in an Administrative Procedure. The proposed changes relocate the requirements from the Technical Specifications to the Administrative Procedure, while providing additional administrative controls in item 13 to Specification 6.5.1.E. Since no changes have been made to the technical content, the relocation is primarily administrative in nature.

These changes are consistent with the guidance in Generic Letters 86-10 and 88-12 and will not reduce the effectiveness of the Fire Protection Program.

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Attachment 111 to JPN-94-033 SAFETY EVALUATION Page 8 of 11 IV. EY_AkilAILON_0EllGNIElCANT HAZAB_DJ_CDXSIDjifLAllON Operation of the FitzPatrick plant in accordance with the proposed Amendment will not involve a significant hazards consideration as defined in 10 CFR 50.92, because:

(1) This change does not involve a significant increase in the probability or consequences of an accident previously evaluated because no modifications, no changes to operating procedure requirements, no reduction in administrative controls and no reduction in equipment reliability are being made as a result of these changes. This proposed amendment relocates the fire protection LCOs  ;

and Surveillance Requirements from the Technical Specifications to an Administrative Procedure. No significant changes in content are being made to the Technical Specification requirements that are being relocated. Operating limitations will continue to be in effect, and required surveillances will continue to ,

be performed in accordance with written procedures and instructions auditable by  ;

the NRC.

Although future proposed changes to the fire protection program elements previously located in the Technical Specifications will no longer be controlled by 10 CFR 50.36, proposed changes to the Fire Protection requirements will be i controlled by the License Condition and plant procedures. Programmatic controls )

will continue to assure that fire protection program changes do not reduce the effectiveness of the program to achieve and maintain safe shutdown in the event of a fire.

(2) The possibility of an accident or malfunction of a different type than evaluated previously in the safety analysis report is not created because no reduction to the fire protection requirements, no modifications, no changes to operating procedure requirements, no reduction in administrative controls and no reduction in equipment reliabilny are being made as a result of these changes. Programmatic ,

controls will continue to assure that fire protection program changes do not  !

reduce the effectiveness of the program to achieve and maintain safe shutdown  !

in the event of a fire.

(3) This proposed amendment does not involve a reduction to the approved fire protection program or Fire Protection Technical Specification requirements because the Technical Specification fire protection requirements are being '

relocated, with no significant change in content, to an administrative procedure.

Since there is no reduction in the requirements, no modifications, no changes to operating procedure requirements, no reduction in administrative controls and no reduction in equipment reliability are being made as a reruit of these changes, there is no reduction in the margin of safety.

Attachment til to JPN-94-033 SAFETY EVALUATION 4

Page 9 of 11 '

V. AFFECT OF CliA_NGES These changes will not adversely affect the following:

ALARA Program Security Program Fire Protection Program Emergency Plan UFSAR NRC Safety Evaluation Report conclusions overall plant operations environment Operating limitations will continue to be imposed, and required surveillances will continue to be performed in accordance with written procedures and instructions auditable by the NRC.

VI. IMELEMENTATION QF THE PRQP_QSED_ CHANGES Implementation is primarily administrative and involves changes to plant procedures.

Thirty days after approval of this technical specification amendment, FitzPatrick will have implemented the changes to AP-01.04 and will comply with the fire protection requirements of the administrative procedure.

l Thirty days af ter approval of this technical specification amendment, FitzPatrick will update plant procedures to reflect relocation of the fire protection requirements.

The changes to the UFSAR will be submitted in the 1995 UFSAR Amendment.

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The relocation of the Fire Protection requirements from the Technical Specifications to i the administrative procedure will not decrease the effectiveness of the Fire Protection program and will not affect the environment. The relocation of the requirements and the bases will not adversely alter or affect the ALARA program. Operating limitations will continue to be imposed, and required surveillances will continue to be performed in l

, accordance with written procedures and instructions auditable by the NRC.

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Attachment til to JPN-94-033 ,

SAFETY EVALUATION Page 10 of 11 l

Vil, CONCLList0NS The incorporation of these changes: a) will not increase the probability nor the consequences of an accident or malfunction of equipment important to safety as previously evaluated in the Safety Analysis Report; b) will not increase the possibility for an accident or malfunction of a different type than any evaluated previously in the Safety Analysis Report; c) will not reduce the margin of safety as defined in the bases for any technical specification; d) does not constitute an unreviewed safety question, except for the necessity of changes to the technical specifications; and e) involves no significant hazards considerations as defined in 10 CFR 50.92.

Vill. BEEEBENCES

1. NRC Generic Letter 86-10, " Implementation of Fire Protection Requirements,"

dated April 24,1986.

2. NRC Generic Letter 88-12, " Removal of Fire Protection Requirements from the Technical Specifications," dated August 2,1988.

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I Attachment 111 to JPN 94-033 j SAFETY EVALUATION l Page 11 of 11 )

l TABLE 1 .I l

TECHNICAL SPECIFICATION / ADMINISTRATIVE PROCEDURE )

CROSS-REFERENCE LOCATORm i Technical AP Technical AP Specification Section<2) Specification Section(2) 1.0.W 1.0 Table 3.12.1 Table 1 3.0.A 1.1.1.A Table 3.12.2 Table 3 3.0. B 1.1.1.B Table 3.12.3 Table 5 3.0.C 1,1,1.C 4.12. A.1 1.2.2.A.1 3.0. D 1.1.1.D 4.12.B.1 1.2.2. B.1 4.0.A 1.2.1. A 4.12.C.1 1.2.2.C.1 4.0.8 1.2.1.B 4.12.D.1 1.2.2.D.1 4.0.C 1.2.1.C 4.12.E.1

  • 2.2.E.1 4.0.D 1.2.1.D 4.12.F.1 1.2.2.F.1 3.12. A.1 1.1.2.A.1 4.12.F.2 1.2.2.F.2 3.12.B.1 1.1.2.B.1 Table 4.12.1 Table 2 3.12.B.2 1.1.2.B.2 Table 4.12.2 Table 4 3.12.C.1 1.1.2.C.1 Table 4.12.3 Table 6 3.12.C.2 1.1.2.C.2 6.2.2.3 1.3.1 3.12.D.1 1.1.2. D.1 6.2.2.4 1.3.2 3.12.E.1 1.1.2. E.1 6.4 1.3.3 i- 3.12.E.2 1.1.2 E.2 6.5.1.E.13 N/A 3.12.F.1 1.1.2.F.1 6.9(B).2 N/A 3.12. F.2 1.1.2.F.2 i

Notes: (1) in the Administrative Procedure (AP), the applicable Bases is located after Section 1.2.1 or 1.2.2, as applicable.  ;

(2) Section number in Attachment 2 of AP-01.04.

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Attachment IV to JPN-94-033 MARKUP _OE_TECHNICALSEECJELCATION PAGES

, (JPTS-93-020) 1 l

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New York Power Authority , -

e JAMES A. FITZPATRICK NUCLEAR POWER PLANT ,

Docket No. 50-333 DPR-59

.. . _ . . = _-

JAFNPP DELETED TABLE OF CONTENTS (Cont'd)

D. ETreiwercy Service Water System -

E. Intake Deicing Heaters /p 240 242 Ad dt Sys 4.12 244a A. igh Pr re W Fire ecti Syste Wat pray Sprin Sys C. B. 2 Di Syst D. C.

ual F' Hose D

Fire action ste p H Det ors .

. Fir 'erpenetrati Sag / F.

5.0 Design Features 5.1 Site 245 5.2 Reactor 245 5.3 245 Reactor Pressure Vessel 5.4 245 Containment 5.5 245 Fuel Storage 5.6 245 Seismic Design 6.0 246 Administrative Controls 6.1 247 Resperisibility 6.2 247 Organization 6.2.1 247 Facility Management and Technical Support 247 6.2.2 Plant Staff 6.3 247a )

Plant Staff Qualifications ,

., 6.4 Retraining and Replacement Traning 248 U-

- 6.5 248 Review and Audit 6.5.1 Plant Operating Review Committee (PORC) 248 248a 6.5.2 Safety Review Committee (SRC) 6.6 250 Reportable Event Action 6.7 253 Safety Umit Violation 6.8 '253 Procedures 6.9 253 Reporting Requirements 6.10 Record Retention 254a 6.11 254g Radiation Protection Program 255 6.12 IndustrialSecurity Program 258 6.13 Emergency Plan 258 6.14 Fire Protection Program 258 6.15 EnvironmentalQualification 258a

'}-

Amendment No. 7,'X ;l(X7/g, }td,J4137

.. . . _ ~ - ...

JAFNPP LIST OF TABLES (Cont'd)

IAhlt Tilla

.P222 4.2 8 Minimum Test and Calibration Frequency for Accident Monitoring 86 Instrumentation 4.61 Snubber Visualinspection interval 161 4.6 2 Minimum Test and Calibration Frequency for Continuous Atmosphere 162a Monitoring System 4.7-1 IDdLETED) 210 4.7-2 Exception to Type C Tests 211 3.121[MddJdripid%tedfrias(((( // /[ ^

3.12'2

_AFVof9x{deftotectedf/ /l // ////2 V 'p6IFin(Hps(eAtations//// // // / ///249Q t I

4.12-1

[t/Spfa/krkhkff///////g 4.12-2 (r )pf f dh Q h //////// /// / A4 4.12 3 hoofa fNe)(ogst'atWn hllll YI l r 4 l l///

6.2-1 Minimum Shift Manning Requirements 260a 6.10 1 Component Cyclic or Transient Limits 261 4

', (DELETED) 244a 5

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Amendment No. 20, 22, 92, *

  • 1, ? 20, !?t,150, * ??, ? 20, ? !t , 210 vi

w .

JAFNPP 1.0 (cont'd)

@ U. Thermal Paramatarg V. Sectrically Disarmed Control Rod

1. Minimum critical power ratio IMCPRI- Minimum value of the ratio of that power in a fuel assembly which is To disarm a rod drive electrically, the four amphenol type calculated to cause some point in that fuel assembly plug connectors are removed from the drive insert and to experience boMng transition to the actual withdrawal solenoids rendering the rod incapable of assembly operating power for all fuel assemblies in withdrawal. This procedure is equivalent to valving out the core. the drive and is preferred. Electrical disarming do6s not eliminate position indication.
2. Fraction of Limiting Power Density - The ratio of the W. HistiNdb6 haler FlieTPfE=6i'o'rt'sysiEm i knear heat generation rete (LHGR) existing at a given ' '

'i location to the design LHGR. The High-14 ore Watsr F ot(ctipe(SysterfIconsisb

3. Maximum Fraction of Limiting Power Density - The pf{aint sourceind, 'ir ; af d' distribution s(ste jJ, with a.ss6ciatetf'pos ryh6stor valves fis6lation[

Maximum Fraction of Limiting Power Density v si. Sut:h val (es r.tFLPD) is the highest value existing in the core of lud(the y,artl hydcafit curb' valves' nd the'first we ad of the,w(ater flo6v al deyid the Fraction of Limiting Power Density (FLPD).

(onsich a mkle or yriter spr$y sups [ste . /

4. Transition Boiling - Transition boiling means the X. Staggered Test Basis boiling region between nucleate and film boiling.

Transition boiling is the region in which both A Staggered Test Basis shall consist of:

nucleate and film bodmg occur intermittently with neither type being completely stable, a. A test schedule for "n" systems, subsystems.

trains or other designated components obtained by dividing the specified test interval into "n" equel subintervals.

b. The testing of one system. subsystem train or Deleted other designated component at the beginning of each subinterval.

Y. Rated Recirculation Flow That drive flow which produces a core flow of 77.0 x 10' lb/hr.

Amendment No. f. (f. . f. If9. If4. If2.188 .

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I Since pages 244a through 244w are being deleted in their entirety, these pages are not shown here for the sake of brevity. A new page 244a will be provided that will state:

"Pages 244a-244w DELETED" S

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JAFNPP DELETED

2. An SRO or an SRO with a license lirnited to fuel handling shall directly supervise all Core Alterations. This person shall have no other duties during this time:
3. A bri ads f fi (5) or e a shall maint ' d to at a des. T clude two ( member f the um crew ce for safe hutdow and M anyAferson requirep othe sseynctio uring,siire anjergency;
4. In the event of illness or unexpected absence, up to two (2) hours is allowed to restore the shift er 't t-M to the minimum complement.
5. The Operations Manager, Assistant Operations Manager, Shift Supervisor and Assistant Shift Supervisor shall hold a SRO license and the Senior Nuclear Operator and the Nuclear Control Operator shall hold a RO license or an SRO license.

i 6. Administrative procedures shall be developed and implemented to limit the working hours of unit staff who perform safety-related functions; e.g., senior reactor operators, health physicists, auxiliary operators, and maintenance personnel who are working on safety-related systems.

Adequate shift coverage shall be maintained without routine heavy use of overtime.

The objective shall be to have operating personnel work a normal 8-hour day,40-hour week while the plant is operating.

However, in the event that unforeseen problems require substantial amounts of overtime to be used or during extended periods of shutdown for refueling, major maintenance or major modifications, on a temporary basis, the following guidelines shall be followed:

a. An individual should not be permetted to work more than 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> straight, excluding shift tumover time.
b. An individual should not be permitted to work more than 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> in any 24-hour period, nor more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> in any 48-hour period, nor more than 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> in any seven day penod, all excluding shift turnover time,
c. A break of at least eight hours should be allowed between work periods, including shift turnover time.
d. Except during extended shutdown periods, the use of overtime should be considered on an individual bases and not for the entire staff on a shift.

Any deviation from the above guidelines shall be authorized by the Resident Manager or the General Manager - Operations, or higher levels of management, in accordance with established procedures and with documentation of the basis for granting the deviation. Controls shall be included in the procedures such that individual overtime shall be reviewed monthly by the Resident Manager or his designee to assure that excessive hours have not been assegned. Routine deviation from the above guidelines is not authorized.

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Amendment No. f,1f1,1f0,1f7, If8,190 -

247a

JAFNPP 6.3 PLANT STAFF QUALIFICATIONS 6.3.1 The minimum qualifications with regard to educational background and experience for plant staff positions shown in FSAR Figure 13.2 7 shall meet or exceed the minimum qualifications of ANSI N18.1-1971 for comparable positions; except for the Radiological and Environmental Services Manager who shall meet or exceed the Qualifications of Regulatory Guide 1.8, September 1975.

6.3.2 The Shift Technical Advisor (STA) shall meet or exceed the minimum requirements )

of either Option 1 (Combined SRO/STA Position) or Option 2 (Continued use of STA  !

Position), as defined in the Commission Policy Statement on Engineering Expertise '

on Shift, published in the October 28,1985 Federal Register (50 FR 43621). When  :

invoking Option 1, the STA role may be filled by the Shift Supervisor or Assistant l Shift Supervisor. (1) '

6.3.3 Any deviation's will be justified to the NRC prior to an individual's filling of one of these positions.

NOTE:

. (1) The 13 individuals who hold SRO licenses, and have completed the FitzPatrick Advanced Technical Training Program prior to the issuance of License Amendment 111, shall be considered qualified as dual-role SRO/ STAS.

6.4 RETRAINING AND REPLACEMENT TRAINING A training program shall be mantasned under the direction of the Training Manager to assure overall proficiency of the plant staff organization. It shall consist of both retraining and replacement traming and shall meet or exceed the minimum requirements of Section 5.5 of ANSI N18.1-1971.

The retraining program shall not exceed periods two years in length with a curriculum designed to meet or exceed the recualification requirements of /

h 10 CFR 55.59.Ms i ,

t/k cosfd he

{r ~ir u e N A -

g tyti' /'c il I

t a f i d Hr g a rai , 7 6.5 REVIEW AND AUDIT Two separate groups for plant operations have been constituted. One of these, the Plant Operating Review Committee (PORC), is an onsite review group. The other is an independent review and audit youp, the offsite Safety Review Committee (SRC).

Amendment No. , f, ,

,1f1, If, 7, If8,190

~ . _ . _ .

JAFNPP (B) Alternates Altemative members shall be W,W4 in writing by the PORC Chairman to serve on a temporary basis; however, no more than two alternates shall participate .in PORC activities at any one time.

(C) Meeting Frequency Meetings will be called by the Charman as the occasions for review or investigation arise.

Meetings will be no less frequent than once a month. >

(D) Quorum A quorum of the PORC shall consist of the Chairman or one of three Vice Chairmen and five members including designated altamates. Vice Chairmen may act as members when not acting as Chairman.

(E) Responsibilities

1. Review plant procedures, and changes thereto, required by Specification 6.8. ,
2. Review proposed tests and expenments that affect nuclear safety.
3. Review proposed changes to the Operating Ucense and Technical Specifications.
4. Review pr&=d changes or modifications to plant systems or equipment that affect nuclear safety.
5. Investigate violations of the Technical Specifications and prepare and forward a report covering evaluation and recommendations to prevent recurrence to the Resident Manager, who will forward the report to the Manager Nuclear Operations and to the Chairman of the Safety Review Committee.
6. Review plant operations to detect potential safety hazards.
7. Review the Secunty Plan (ncluding the Safeguards Contingency Plan) and implementing procedures annusty.
INSERT A ITEMS 8 THROUGH 12 FROM PAGE 250 Amendment No. h,f,178 249
8. Rsvisw the Eastgency Plan end icplsmanting proceduras annually.
9. Perform special review and/or investigations at the request of the Resident Manager.
10. Review-of all Reportable Events. l
11. Review the Offsite Dose Calculation Manual (ODCM) and implementing procedures at least once per 24 months.
12. Review the Process Control Program (PCP) at least once per 24 months.

< (F) Authority The PORC shall function to advise the Resident Manager on all _

matters related to nuclear safety and environmental operations. The PORC shall recossend approval or disapproval to the Resident Manager ,

of those items considered in 6.5 1E (1) through (4) and determine if l g items considered in 6.5 1E (1) through (5) constitute unreviewed w safety questions, as defined in 10 CFR 50.59.

i 0

'I k In the event of a disagreement between the PORC and the Resident foH Manager, the Chairman of the SRC and the Executive Vice President-Nuclear Generation, or their designated alternates, shall 0 be notified within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and written notification provided on the I next business day; however, the Resident Manager shall have U responsibility for resolution of such disagreement pursuant to o

Section'6.1. .

oc I I F- (G) Records

  • i j $ Minutes of all meetings of the PORC shall be recorded and numbered. 7 w Copies will be retained in flie. Copies will be forwarded to the b Chairman of the SRC and the Executive Vice President-Nuclear y Genera.t lon.

iO E- (H) Procedures  :

Conduct of the PORC and the mechanism for implementation of its responsibilities and authority are defined in the pertinent Administrative Procedures.

6.5.2 SAFETY REVIEW COMMITTEE (SRC)

FUNCTION 6.5.2.1 The SRC shall function to provide independent review and audit of

  • designated activities in the areas of:
a. Nuclear power plant operations ,
b. Nuclear engineering
e. Chemistry and radiochemistry
d. Metallurgy
e. Instrumentation and control Amendment No. R. J4', M Nr 110 250

l JAFNPP (B) SPECIAL REPORTS I

1. Rfteen copies of the Evaluation Report of the results of the first five years of '

performance of the nerwiestructive inspection listed in Table 4.6-1 of Technical Specifications 4A.F, Structural Integrity, relating to the FitzPatrick a in-service irWri program shall be submitted to the NRC, Director of 4

Operating Reactors, within three months of the ceirif4etion of the fifth year {

of theprogram. i

2. b pf yst M N iny _

3 .A.

/12.

.d.2,p. 2.8 ,3.1)tC.2,)d2. , 1 l

p f 6.10 RECORD RETENTION DELETE (A) The following records shall be retened for at least five years:

1. Records and logs of fac5ty operation covering time intervals at each power level.
2. Records and logs of principal maintenance activities, inspections, repair and replacement of pnncipal items of equipment related to nuclear safety.
3. All Reportable Events.
4. Records of surveillance acevities, irief,ections and calibrations required by these Technical W
5. Records of reactor tests and experiments.
6. Records of changes made to Operating Procedures.
7. Records of radioactive shipments.
8. Records of sealed source lsak tests and results.
9. Records of annual physicalirwentory of all source material of record.

J 4-

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, ' Arrerir,T. erd No. [ , 176

LNSEBLA

13. Review of the FitzPatrick Fire Protection Program and implementing procedures and changes thereto.

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Attachment V to JPN-94-033 M A R KtlP_OF_O P E R AIJING_L,l_CINRE P A G ES (JPTS-93-020)

New York Power Authority JAMES A. FITZPATRICK NUCLEAR POWER PLANT Docket No. 50-333 DPR-59

(3) Pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use, at any time, any byproduct, source, and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use, at any time, any byproduct, source and special nuclear material h without restriction to chemical or physical form, z for sample analysis or instrument calibration: or E associated with radioactive apparatus, components y or tools. e (5) Pursuant to the Act and 10 CFR Parts 30 and 70, to y possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. The license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70s and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect s and is subj ect t to the additional conditions specified or incorporated below:

(1) Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2436 megawatts (thermal).  ;

(2) Technical Specifications I The Technical Specifications contained in Appendi-ces A and B, as revised through Amendment No. *,

are hereby incorporated in the license. The licensee shall operate the facility in accordance INSERT B with the Technical Specifications, i I

(3) Fire Protection T e Iep/e'e co .ett t ay mo oce ic wit ions and req denti'iedij/uded Tab s o hl e l

) .1 Saf(pr(d ty o he j C's 'ames 3aluptiongepor (SER)

. Fitpfatr Fire /Proterctio

/Nz a/

Thead modf'fic ions'/

dvie , dacdd A gust 1 1979 7

3) ha b omp1Ned in accor ance'41th pfie s edufe 0l i b 3 and 42 of e SER or upp ent/ /
  • Each amendment updates this paragraph to indicate the latest amendment to the License. '

-3a- ,

[t t)d Po r thor he S te New York a

review, pr,for i emenpfti prov,1de f Commissi n do t ai Commissio approyral o the final de'sig of m i catio s a indic ted i sect on 3 of /

the fet Ev uati

/ Re ort.

/

/

E cept fire ro o the ctio dif}c/ation descrJi ed the appr ved plarf and a}fproved'as a 'esuld of g>

z

/Co is on review of the/ James,I. Fitz trick N lear E/

we lant/ Fir Protection Program /thef4ower Authopi- g/

ty the Sta of Np6 York 4s aut ake w ch ges o y e Program witti, cut pn/f'ori or 4d toommisionap/

u

/ ova provided th"at such'changds d not t'esult dn a 4/

/ decrease in the/effecti'venesgof plfe Profram. j/

1, cense requ red rd i 'l he a' minis a-ive' contro'ls identified'in administfativecontrofsothe,E!peme ctio of the S The r thad pre ' ire s ategy fi lans '$ hall e in e y 1979 Pre-fire str egy p ns a[ffect to betfyeffegtive Oct6ber 1Jan rylg980 (4) Systems Integrity The licensee shall implement a program to reduce leakage from the systems outside containment that would or could contain highly radioactive fluids during a serious transient or accident to as low as practical p levels. This program shall include the following:

1. Provisions establishing maintenance and periodic visual inspection requirements, and
2. Leak test requirements for the systems at a @

frequency not to exceed operating cycle intervals. g e

(5) Iodine Monitoring

@ 1 2 1 The licensee shall implement a program which will d ensure the capability to accurately determine the $

airborne iodine concentration in areas vital to the mitigation of or recovery from an accident. This program shall include the following:

1. Training of personnel, l
2. Procedures for monitoring, and
3. Provisions for maintenance of sampling and analy-sis equipment.

INSEIII3 1

The licensee shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility and as approved in the SER dated November 20,1972, the SER Supplement 1 dated i February 1,1973, the SER Supplement 2 dated October 4,1974, the SER dated August 1,1979, the SER Supplement dated October 3,1980, the SER Supplement dated February 13,1981 and the NRC Letter dated February 24,1981 subject to the following l provision. -

The licensee may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

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Attachment VI to JPN-94-033 MARKUP _QE_UESAR PAGES (JPTS-93-020)

(Note: deletions are shown in strikeout, and additions are shown in bold.)

New York Power Authority JAMES A. FITZPATRICK NUCLEAR POWER PLANT Docket 50-333 DPR-59

Attachment Vil to JPN-94-033 l

MARKUP _OF_ APED 4 PAGES (JPTS-93-020) f

)

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New York Power Authority JAMES A. FITZPATRICK NUCLEAR POWER PLANT Docket 50-333 DPR-59

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NEW YORK POWER AUTHORITY JAMES A. FITZPATRICK NUCLEAR POWER PLANT  !

ADMINISTRATIVE PROCEDURE F

f Q VIIf E H.EN Ts, TECH SPEC RELATED %ISTS AND TABLES

REVIEWED BY: PLANT OPERATING REVIEW COMMITTEE MEETING NO. ^4 ^ 3 'l DATE 3 30 4

. ( /

APPROVED BY: /(vCJ //L/6 DATE 3ijJ^ f7j, Y RESPONSIBK PROCEDURE OWNER APPROVED BY:

/v/br/ W \/

Y/ s/,/n DATE // v/' '

RESIDENT' MANAGER '

EFFECTIVE DATE: A n il 14, 100i FIRST ISSUE D FULL REVISION O LIMITED REVISION 5 INFORMATIONAL USE *

  • TSR
                                        • w****** ***************************

^"" " 8 ^*'=

: qOm e,<,,C03TR07 WS
  • w************************* dd'$

PERIODIC REVIEW DUE DATE J ,'J "J C " 1 0 0 5

. _ .__ - '-- _ _ _ _ - - - - ' ~

~ -

TECH SPEC RELATED ISTS AND TABLES

.. 1 REVISION SUletARY SHEET

REV. NO. REASON FOR CHANGE 5 -

Added ability to make editorial or typographical changes.to Attachment 1 without safety evaluations.

+

Removed Isolation Signal "B" from valves 27AOV-131A and B and 27AOV-132A and B.

4 .

Corrected 13MOV-27 Isolation Signal-codes per JAF-SE-93-117.

Revised stroke time requirements for 27MOV-122 and 27MOV-123 from 5 to 8 ,

seconds per JAF-SE-93-104.

3 .

Changed stroke time requirement for 13MOV-27 (Penetration 210A) from 5 to 6.25 seconds per JAF-SE-93-093.

Added 10R5R-729A to penetration 225A and 10RBR-7293 to penetration 225B per Tech Spec Amendment (194..

Updated reference from AP-1.3 to AP-02.04 1

2 .

Moved 27S07-119F2 and 27SOV-119F1 from penetration 26A.to 216 per JAF-SE-91-067.  ;

Changed 46ESW-15B designator'to 46ESW-15A 1 for penetration 63 and 46ESW-15A .

designator to 46ESW-15B for penetration' l

67. These were incorrect on Tech Spec ]

Table 3.7-1 removed 12/91. Operations j and ORG have verified this is correct r

+

Misc. typographical error corrections. ,

from Tech Spec table' conversion to' AP. . l Verified by ORG group for accuracy.

$~7 Rev . Ho . . Page 2 of -BB-4

________m._ - - . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _

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f blQ t/IR ErlE/V TS, l w-TECH SPEC RELATED ISTS AND TABLES

1 TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE . . . . . . . . ................ 4 2.0 APPLICABILITY . . . . . ................ 4

3.0 REFERENCES

. . . . . . . ................ 4 4.0 REQUIREMENTS . . . . . . ................ 4 5.0 DEFINITIONS . . . . . . ................ 4 6.0 RESPONSIBILITIES . . . . ................ 4 7.0 SPECIAL INSTRUCTIONS . . ................ 5 8.0 PROCEDURE . . . . . . . ................ 5 9.0 ATTACHMENTS . . . . . . ................ 5

1. PRIMARY CONTAINMENT ISOLATION VALVES . . . . . . . . 6
2. PIRE P A 0 TE C T T Ott/ A G-()L) Ti1Erisit/ TS ,,.,,c 2 LJ r7 Rev. No. Page 3 of 23

, &Q UIR E ME-N TS g -

TECH SPEC RELATED* LISTS AND TABLES

To provide administrative controls for lists and tables removed from Tech Specs and FSAR.

, -2.O APPLICABILITY Quseeetenbj Plantf---;:rret ists and tables removed from Tech Specs and i

-FSAR as allowed by the NRC.

3.O REFERENCES 3.1 Performance References 3.1.1 AP-02.04, Control of Procedures

  • 3.2 Developmental References 1

3.2.1 NRC Generic Letter 91-08, Removal of Component-List From Technical Specifications, dated 5/6/91 ,

3.2.2 AP-01.02, License Administration

  • 3.2.3 Technical Specification Amendment No. .173 for James ,

A. FitzPatrick Nuclear Power Plant.(TAC No. i e M79489), dated December 2, 1991 4.O REQUIREMENTS I

- 3.2.4 NRC Generic Letter 86-10, ' implementation of Fire Protection NONE Reqwoments,' dated Apnl 24,1986.

t 3.2.5 NRC Generic Letter 8812, " Removal of Fire Protection Requirements 5.O DEFINITIONS from the Technical Specificabons,' dated August 2,1988.

j NONE -

3.2.s Technical specification Amendment No. XXX for James A. FitzPatrick-Nuclear Power Plant (TAC No. MYYY), dated ZZZ.

l 6.O RESPONSIBILITIES '

6.1 NYPA Nuclear Generation Personnel 1

Submit changes to this procedure as directed in Section 8.0, )

PROCEDURE.

6.2 ORG/ Licensing Manager (ORG)

Ensures'a technical review is completed on changes to the Attachments to this procedure and that non editorial or typographical changes have a'10 CFR 50.59 Safety Evaluation.

c 6.3 Technical Services Manager Ensure changes-to any attachment of this procedure are j technically reviewed for completeness and accuracy. '

57 .i Rev. No. Page 4 of 19- 1

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x Q v 1REMsivrs) J f d TECH SPEC RELATEDVIISTS AND TABLES

  • AP-01.04 7.0 SPECIAL INSTRUCTIONS This procedure contains items which were previously included 4ke inpTechnical Specifications. ,

8.0 PROCEDURE })e a_ Ya c f rs en]3 soy l115froMC '[$l 8.1 Changes to :ttac hent [may be proposed by any person working for NYPA Nuclear Generation Department.

  • NOTE: Additional attachments will be adde to this procedure as abics and lists are removed from ech Specg 8.2 The Technical Services Manager shall ensure changes to Attach cr.t ' are reviewed for technical accuracy and d completeness 8.3 In addition to the requirements of AP-02.04, the ORG/ Licensing Manager shall ensure changes to Attach:.cnt 14 are reviewed and evaluated prior to receiving PORC review, including:

8.3.1 Independent technical review by Technical Services department.  ;

8.3.2 For editorial and typographical changes, includes sufficient documented basis for concluding that changes are editorial or typographical in nature.

8.3.3 For non-editorial and typographical changes, an l approved 10 CFR 50.59 Safety Evaluation justifying '

proposed changes.

9.0 ATTACHHENTS l

1. PRIMARY CONTAINMENT ISOLATION VALVES 2, FIRE PR O TE C T 10 N R &cQ V1/R&+l& N TS I

l W-] Ul f t'ti f nS Y , Yif Ys a n h $ frS S3 Rev. No. -*r- Page 5 of 23

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IECH SPEC RELATED ISTS AND TABLES

. 29MOV-77 B,C,D,E,M,P,R 15 Closed 9A Feedwater 34FWS-281 Reverse Flow NA Open 34NRV-111A Reverse Flow NA Open RCIC Disch. 13MOV-21 R NA Closed .

RWCU Return 12MOV-69 A,F,J,R 20 Open 9B Feedwater 34FWS-28B Reverse Flow NA Open 34NRV-111B Reverse Flow NA Open HPCI Disch. 23MOV-19 R NA Closed 10 RCIC Turbine 13MOV-15 K,R 12 Open Steam ** **==*= * *= ***************** ****** = *=* *=

Supply 13MOV-16 K,R 12 Open N

Rev. No. 5 Page 6 of 23

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TECB SPEC RELATED ISTS AND TABLES

l CONTAINMENT PENETRATION VALVE Imm2* PION CLOSE TIME NORMAL REMARRS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7)  ;

11 HPCI Turbine 23MOV-15 L,R 13.5 Open Steam **** =* *** * ==*'**'** =*c**** *******

Supply 23MOV-16 L,R 13.5 Closed 23MOV-60 L,R 13.5 Open 12 RER Shutdown 10MOV-18 A,F,R,U 38 Closed Cooling a** ******************************************a .

Suction 10MOV-17 A,F,R,U 38 Closed Testable 13A RER Shutdown 10AOV-68A Reverse Flow NA Closed chk viv Cooling and Notes 3,10 LPCI to ********************************************************

Reactor 10MOV-25A R,X 120 Closed Note 6 10MOV-27A R 90 Open Throttle valve Note 6 Testable l 13B RER Shutdown 10AOV-68B Reverse Flow NA Closed chk viv Cooling and Notes 3.10 i LPCI to ********************************************************

Reactor 10MOV-25B R,X 120 Closed Note 6 10MOV-27B R 90 Open Throttle valve Note 6 i

14 RWCU Suction 12MOV-15 A,F,J,R 20 Open 12MOV-18 A,F,.7,R,V,Y 20 Open 1

S'7-Rev. No. Page 7 of 20

R E Q U 2 R E M En' TS J

TECH SPEC RELATED LISTS AND TABLES

i l

l ATTACHMENT 1 Page 3 of 18 PRIMARY CONTAINMENT ISOLATION VALVES l l

l CONTAINMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) i Testable  !

16A Core Spray 14AOV-13A Reverse Flow NA Closed chk vlv l Notes 3,10 14MOV-12A R NA Closed Note 6 14MOV-11A R NA Open Testable 16B Core Spray 14AOV-13B Reverse Flow NA Closed chk vlv Notes 3,10 14MOV-12B R NA Closed Note 6 14MOV-11B R NA Open 18 Drywell . 20MOV-82 A,F,R 30 Open Floor Drain * *******.. *=** *=********* * * * == ** ****

Sump Disch. 20AOV-83 A,F,R NA Open 19 Drywell 20MOV-94 A,F,R 30 Open -

Equip. Drain *** *** ====** ** *=* *** *~** ******=* * ***

Sump Disch. 20AOV-95 A,F,R NA Closed Note 11 22 Instrument 39IAS-22 Reverse Flow NA Open Air or ********************************************************

Nitrogen 27SOV-141 R NA Open Fall in open position to ensure adequate pneumatic supply SF Rev. No. 5 Page 8 of -

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TECH SPEC RELATED ISTS AND TABLES

  • AP-01.04 ATTACBMENT 1 Page 4 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAIMMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARRS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7)

To drywell 23 RBCLCW to 15AOV-130A R NA Open cooler Drywell .............................**............... assembly A 15RBC-24A Reverse Flow NA Open & equipment

............................................................ sump cooter ESW to 46ESW-16B Reverse Flow NA Closed Drywell To drywell 24 RBCLCW to 15AOV-130B R NA Open cooter Drywell . . . . * * . . . . . . . . . . . . . . . . . . * * . . * * * . . . . . . * * * . . . * . assembly 8 15RBC-24B Reverse Flow NA Open t ESW to 46ESW-16A Reverse Flow NA Closed Drywell 25 & 71 Drywell 27AOV-112 A,F,H,R,E 5 Closed Purge Inlet ** *

(Air) 27AOV-111 A,F,H,R,E 5 Closed Drywell 27AOV-131A A,F,R,5 5 Closed Purge Inlet .**********............................... *...

(Nitrogen) 27 CAD-68 Reverse Flow NA Closed 27AOV-131B A,F,R,5 5 Closed l 27 CAD-69 Reverse Flow NA Closed 26A & 26B Drywell 27AOV-113 A,F,B,R,E 5 Closed Purge Inlet .**.**.a......................**........**.***.

(Air and/or 27AOV-114 A,F,H,R,5 5 Closed Nitrogen) ...............................................

27MOV-113 A,F,H,R,5 5 Closed 27MOV-122 A,F,H,R,E 8 Closed S' ?

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R E Q VI R E MEN i~J, f L J TECH SPEC RELATED %ISTS AND TABLES

ATTACHMENT 1 Page 5 of 18 l l

PRIMARY CONTAINMENT ISOLATION VALVES l CONTAINNENT PENETRATION VALVE ISOIATION CLOSE TIME NORMAL RENARK8 PENETRATION FUNCTION NUMBER SIGatAL (SEC)(5) STATUS (7) 26A Drywell 27SOV-120K2 A,F,R,2 NA Open From elev.

Atmosphere ******************* *** ************************ 310' 6* to Sample 27SOV-120E1 A,F,R,2 NA Open 27PCA-101A (Suction) Note 13 27SOV-122E2 A,F,R.2 NA Closed From elev.

j ................................................ 343' to 27SOV-122E1 A,F,R,2 NA Closed 27PCA-101A Note 13 30a Instrumen- Various NA NA Open Typical of '

tation * ***** ** *** * ***** * * *** *** ***** ** ** Gp A Inst.

Various Excess Flow NA Open penetra.

31Ac Recircu- 02-2RNR-13A Reverse Flow NA Open lation pump * ** .*. - ** . ...* .*.* -

seal purge 02-2SOV-001 B,F,R NA Open 31Bc Recircu- 02-2RWR-13B Reverse Flow NA Open j 1ation pump ** * .- * * ..**.- **- *- *

atmosphere ****************************************** ***** 276' to sample 27sOV-135A A,F,R,2 NA Open Radiation (Suction) Monitors Note 12 5' 7-Rev. No. 5 Page 10 of A

. bQ uz es m u rs, l t __ s 1 TECH SPEC RELATED ISTS AND TABLESO AP-01.04 ATTACHMENT 1 Page 6 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARK 8 PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) i From elev.

31Bd Drywell 27SOV-135D A,F,R,Z NA Open 7.96* to atmosphere ********************************************** Radiation sample 27SOV-135B A,F,R,5 NA Open Monitors (Suction) Note 12 35B Traversing 07SOV-104A A,F,R NA Open Hotes 8,14 In-core =** * * * . * . * . . * * . * * * * . . * . * * . * * * . . . * * * . * * . * * * * * * . . . * .

  • Probe "A" 07EV-104A R NA Open Notes 14,15 35C Traversing 07SOV-104C A,F,R NA Open Notes 8,14 In-core ****.************************=**************************

Probe "C" 07EV-104C R HA Open Notes 14,15 35D Traversing 07SOV-104B A,F,R NA Open Notes 8,14 In-core ********************************************************

Probe "B" 07EV-104B R NA Open Notes 14,15

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( b h Y.f N E N E A I TECH SPEC RELATED LISTS AND TABLES

  • AP-01.04 ATTACHMENT 1 Page 7 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOLATION CLO3E TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) 37A Control 03SOV-120 NA NA Closed Typical of 37B Rod ******** ===** *** * *'******'*************==* 137 Control 37C Drive 03SOV-123 NA NA Closed Rod Hyd.

37D (Inlet) ************************** * ***** ***** *****

Cont. Units 03AOV-126 NA NA Closed Viv. listed

................................................ Isolate the 03CRD-138 Revei'se Flow NA Open CRD insert and scram inlet line.

Note 4 38A Control 03SOV-121 NA NA Closed Typical of 38B Rod **= ****** **.* *** *=**** * ***** **= ***== ** 137 Control )

38C Drive 03SOV-122 NA NA Closed Rod Hyd.

38D { Outlet) **=****= **********=*=* * ** * *** **** ****** Cont. Units 03AOV-127 NA NA Closed Viv. Listed

................................................ isolate the CRD w/ draw and scram outlet line Note 4 t

39A RER 10MOV-31A G,S,R 60 Closed Note 2 Containment ****=****==****** * *=****==*** **=*****= *****

Spray 10MOV-26A G,S,R 60 Closed 10RHR-52A NA NA Closed 39B RHR 10MOV-31B G,S,R 60 Closed Note 2 Containment ************ ************************* *********

Spray 10MOV-26B G,S,R 60 Closed 10RHR-52B NA NA Closed I

41 Recirc 02-2AOV-39 B,C,R NA Open i Loop ***=* **** '** ***************** **

  • Sample 02-2AOV-40 *==',R B,C NA Open 59 Rev. No. 5 Page 12 of 22

jfSHQ 01RG MEivi3, TECH SPEC RELATED ISTS AND TABLESe AP-01.04 ATTACHMENT 1 Page 8 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOLATION CIASE TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIMAL (SEC)(5) STATUS (7) 42 Standby 11SLC-17 Reverse Flow NA Closed LLquLd - =* ... ..*. ...*.... ..... ... ** . *- ,

Control 11SLC-16 Reverse Flow NA Closed 45 Drywell 16-1AOV-101A A,F,R,2 NA Open Pressure *=*=** =*** ** =* ****** *=* ***. ****

  • Sensing 16-1.AOV-101B A,F,R,Z NA Open 50c Instrumen- Various NA NA Open Typical of tation- Gp.B Inst.

Sensing Penet.

DW Pressure To elev.

52a Drywell 2750V-125C A,F,R,Z NA Open 282' from Atmosphere .*......... .........*...................*.... Radiation Sample 27SOV-125A A,F,R,Z NA Open Monitors (Return) Note 12 To elev.

< 55b Drywell 27SOV-125D A,F,R,Z NA Open 296' from Atmosphere * * * * * . . * * . . . . * * * * . * * * . * * * * . * * . * . * * * * * * * . * * * *

  • Radiation Sample 27SOV-125B A,F,R,Z NA Open Monitors (Return) Note 12 57c CAD Supply -27SOV-145 R NA Open Fait in to Instru- open post. ,

mentation to ensure in Drywell adequate pneumatic supply 39IAS-29 Reverse Flow NA Closed l

)

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E-& Ll1$ N W I TECB SPEC RELATED ISTS AND TABLES

PRIMARY CONTAINMENT ISOLATION VALVES CONTAIMMENT PENETRATION VALVE ISOLATICII CLOSE TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) 58b Drywell 2780V-122F2 A,F,R,3 NA Closed From elev.

Bydrogen *= * - *' * * * **'*

343' 3* to Sample 27SOV-122F1 A,F,R,5 NA Closed 27PCA-1018 Note 13 i

50c Drywell 27SOV-120F2 A,F,R,2 NA Open From elev.

Hydrogen ************************************* ******* 310' 6* to Sample 27SOV-120F1 A,F,R,3 NA Open 27PCA*1018 Note 13 58d Drywell 27sOV-123F2 A,F,R,Z NA Closed From elev. ,

Hydrogen ********************************************** 276' 6* to Sample 27SOV-123F1 A,F,R,Z NA closed 27PCA-1018 Note 13 59 Drywell 27SOV-123E2 A,F,R,E NA Closed From elev.

Hydrogen ********************************************** 276' to Sample 27SOV-123E1 A,F,R,Z NA Closed 27PCA-101A Note 13 62 RBCLCW or 15AOV-131B R NA Open From ,

ESW from ********************************************** drpell '

Drywell 15RBC-26B NA NA Open - cooler assembly B 63 RBCLCW to 15AOV-132A R NA Open To recircu-Drywell a********************************************* lation pump 15RBC-21A Reverse Flow NA Open A and motor

....e..................................................ee*** Coolers ESW to 46ESW-151 Reverse Flow NA Closed Drywell 1 64 RBCLCW or 15AOV-133A R NA Open From recir- '

ESW from ********************************************** culation Drywell 15RBC-22A' NA NA Open pump A and str coolers i

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Rev. No. 5 Page 14 of 23

RhQ01REH5/C'is, TECB SPEC RELATED ISTS AND TABLES

  • AP-01.04 ATTACHMENT 1 Page 10 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) 65 RBCLCW or 15AOV-134A R NA Open From drywell ESW from ****=***** ****** **********************= **= equipment Drywell 15RBC-33 NA NA Open sump cooler 66 RBCLCW or 15AOV-131A R NA Open From drywell ESW from *** **=*.*****..***********.****=*** *=*== cooler Drywell 15RBC-26A NA NA Open assembly A 67 RBCLCW to 15AOV-132B R NA Open To recircu-Drywe11 *=**== ***** ==**************** ********=*** tat 1on pump 15RBC-21B Reverse Flow NA Open B and motor
              • .****.* .********.************************..********* coolers ESW to 46ESW-15B Reverse Flow NA Closed Drywell 68 RBCLCW or 15AOV-133B R NA Open From recir-ESW from
                            • *.*********************** **** culation Drywell 15RBC-22B NA NA Open pump B and str coolers i 202B Vacuum 27AOV-101A R NA Closed VBs open Breaker *********************** ******* * =** ******* a when suppres-Reactor 27AOV-101B R NA Closed sion chamber B1dg to *************** ***** **=******=*= * ** ** ** pressure is Suppression 27VB-6 Reverse Flow NA Closed 0.5 psid Chamber *********************************************** below Reactor 27VB-7 Reverse Flow NA Closed Building pressure 1

ff Rev. No. 5 Page 15 of 23 l

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TECH SPEC RELATED LISTS AND TABLES

  • AP-01.04 ATTACHMENT 1 Page 11 of Ib PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS '(7 )

J03A Suppression 27SOV-119E2 A,F,R,Z NA Closed. To Chrunber ***** ***=** *** ****** *********=********** 27PCA-101A Atmosphere 27SOV-119El A,F,R,Z NA Closed Note 13 Sample (Suction) 203B Primary 27SOV-124E2 A,F,R,Z NA Open From C o nt a inme nt * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *

  • 27PCA-101A Analyzer 27SOV-124E1 A,F,R,Z NA Open Note 13 and Post *** ** ***' ** **** ** *************** ** ** ***=* .

Accident 27SOV-124F2 A,F,R,Z NA Open From Sample ****. *.... *................**.- * - -

27PCA-1018 (Return) 27SOV-124F1 A,F,R,Z NA Open Note 13 205 Pressure 27AOV-117 A,F,H,R,Z 5 Closed Suppression =** * * = * * * * * * * * * * * = * . * * . . . = * * = = = *

  • Chamber 27AOV-118 A,F,H,R,Z 5 Closed Purge *************=****** ******* * **************

Exhaust 27HOV-117 A,F,B,R,Z 5 Closed (Air or ***== * * '* * * **..****=** * **

  • Nitrogen) 27MOV-123 A,F,B,R,Z 8 Closed 210A RER to 10HOV-34A G,R 70 Closed Throttle vlv Suppression for flow test Pool and suppression pool cooling Note 2 RER to 10MOV-16A R 4 NA Open Pop min. flow Suppression - * * *- ** - - '- - - *-

Pool 10MOV-21A G,R NA Closed Ht Exch drain I 10MOV-167A R NA Closed Ht Exch vent 10RHR-95A Reverse Flow NA Open RHR Keep-Full l sin flow l RCIC 13MOV-27 R 6.25 Closed Pap min flow Core Spray 14MOV-5A R NA Open Pap min flow Test to ********** **************** ********* **

Suppression 14HOV-2EA G,R 45 Closed Throttle viv Pool for flow test l

........................................................ I 14 CSP-62A Reverse Flow NA Open Core Spray Keep-Full sin flow S32 Rev. No. - Page 16 of 23

1 Y5! ENEUI TECH SPEC RELATED ISTS AND TABLES

  • AP-01.04 ATTACHMENT 1 Page 12 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOIATION CLOSE TIME NORMAL REMARKS l PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) i i

l Throttle viv l 210B RER to 10MOV-34B G,R 70 Closed for flow test Suppression a suppression Pool pool cooling Note 2 10MOV-16B R NA Open Pop min flow 10MOV-21B G,R NA Closed Ht Exch drain 10MOV-167B R NA Closer! Ht Exch vent 10RHR-95B Raverse Flow NA Open RHR Keep-Full min flow Core Spray 14 CSP-62B Reverse Flow NA Open Core Spray Test to Keep-Full Suppression min flow Pool HPCI 23MOV-25 R 10 Closed Pop min flow

, Core Spray 14MOV-5B R NA Open Pap sin flow Test to ***.=*** * * **...**. ..***...*** **** ******** ** **

  • Suppression 14MOV-26B G,R 45 Closed Throttle viv Pool for flow test l

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TECH SPEC RELATED ISTS AND TABLES

  • AP-01.04 ATTACHMENT 1 Page 13 of 16 PRIMARY CONTAINMENT ISOLATION VALVES CONTAIIOMNT PENETRATION VALVE ISOI.ATION CLOSE TIME NORMAI. REMARKS I PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) .

1 Throttle viv l 211A RHR to 10MOV-38A G,R,S 10 Closed for Suppression suppression  ;

Spray Header chamber spray Note 2 10MOV-39A G,R NA Closed Note 2 )

i Throttle viv 211B RER to 10MOV-3BB G,R,S 10 Closed for Suppression suppression Spray Header chamber spray Note 2 10MOV-39B G,R NA Closed Note 2 212 RCIC 13RCIC-04 Reverse Flow NA Closed Turbine **====**** *****= **** ************==** *= =*

Exhaust 13RCIC-05 Reverse Flow NA Closed 214 HPCI 23HPI-12 Reverse Flow NA Closed Turbine ****** * ******** **********=***=* * ***= *

Exhaust 23HPI-65 Reverse Flow NA Closed 216 Drywell 27SOV-119F1 A,F,R E NA Closed From elev.

Atmosphere ********* ******** ********* * ***=************ 257* 6' to Sample 27SOV-119F2 A,F,R,5 NA Closed 27PCA-1018 (Suction) Note 13 59-

  • Rev. No. Page 18 of

/$EQd.I TECB SPEC RELATED ISTS AND TABLESo AP-01.04 ATTACHMENT 1 Page 14 of 18 PRIMARY CONTAINMENT ISOLATION VALVES CONTAINMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARKS PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) 218 Torus 16-1AOV-102A A,F,R,Z NA Open Pressure ==*=** ****==****= * *** *** **** *=******

Sensing 16-1AOV-102B A,F,R,Z NA Open 220 Torus 27AOV-116 A,F,H,R,Z 5 Closed Purge Inlet ** *...=..**......... .......... ..... * ...

(Air) 27AOV-115 A,F,B,R,Z 5 Closed Torus 27AOV-132A A,F,R,Z 5 Closed Purge Inlet *****.*- **...**..........................*=.

(Nitrogen) 27 CAD-67 Reverse Flow NA Closed 27AOV-132B A,F,R,Z 5 Closed 27 CAD-70 Reverse Flow NA Closed 221 RCIC- 13RCIC-07 Reverse Flow NA Closed Vacuum to Torus 222 HPCI-Turb 23HPI-13 Reverse Flow NA Closed Drain Trap to Torus 224 RCIC-Pump 13MOV-41 R NA Closed i Suction * * =** ** **=* ****** ** **. ******=* ****

l (Torus) 13HOV-39 R NA Closed i I

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TECHSPECRELATEDYISTSANDTABLES* AP-01.04 ATTACHMENT 1 Page 15 of 1b l PRIMARY CONTAINMENT ISOLATION VALVES l

1 CONTAINMENT PENETRATION VALVE ISOLATION CLOSE TIME NORMAL REMARES PENETRATION FUNCTION NUMBER SIGNAL (SEC)(5) STATUS (7) 225A RHR-Pump 10MOV-13A R NA Open Suction **********************************************

10MOV-13C R NA Open 10RHR-729A NA NA Closed 225B RHR-Pump 10MOV-13B R NA Open Suction **********************************************

10MOV-13D R NA Open 10RHR-729B NA NA Closed 226 HPCI-Pump 23MOV-58 L,R NA Closed Suction **********************************************

(Torus) 23MOV-57 L,R NA Closed 227A Core Spray 14MOV-7A R NA Open Pump Suction (Torus) 227B Core Spray 14MOV-7B R NA Open e' Pump Suction (Torus) 228 Condensate 33CND-102 NA NA Closed to Torus i

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TECB SPEC RELATED ISTS AND TABLES

  • AP-01.04 ATTACHMENT 1 Page 16 of 18 PRIMARY CONTAINMENT ISOLATION VALVES Isolation Sicnal Codes Sional Descriotion A* Reactor vessel low water level- This is the highest of the three low water level signals. A scree occurs at this level.

B* Reactor vessel low-tow-low water level- This is the lowest of the three low water signals.

C* High radiation- main steam line D* Line break main steam (high steam flow)

E* Line break- main steam (tunnet high temperature)

F* High drywell pressure G Reactor vessel low-low-low water level or high drywell pressure H* Containment high radiation J' Line break in Reactor Water Clean-up Syster- high area temperature K* Line break in RCIC System steam line to turbine (high steam line area temperature, high steam flow, low steam line pressure, or high turbine exhaust diaphrage pressure)

L' Line break in HPCI Systes steam line to turbine (high steam line space tesperature, high steam flow, low steam line pressure, or high turbine exhaust diaphrage pressure)

M* Low condenser vacuum in run mode only P* Low main steam line pressure at intet to main tertine (RUN pode only)

R* Remotemanualswitchfreecontrolroom(automaticGroupA&Bisolationvalvesare capable of remote manual operation from the control room)

S Low drywell pressure T Low reactor pressure permissive to open Core Spray and RHR-LPCI valves U* High reactor vessel pressure or high drywell pressure Y High temperature at outlet of Reactor Water Clean-up systes non-regenerative heat exchanger X* Reactor vessel low water level or high drywell puissure when both shutdown cooling suction valves (10MOV-17 and 10MOV-18) are not fully closed and reactor vesset pressure is below 75 psig Y Standby Liquid Control System actuated 2* Reactor building ventilation exhaust high radiation

  • These are the isolation functions of the Primary f.ontainment and Reactor Vessel TF Rev. No. 5 Page 21 of 22 l

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TECH SPEC RELATED ISTS AND TABLES

  • AP-01.04 Isolation Control Systes: other functless are given for information only. Setpoints for isolation signals are located in Tables 3.2-1 and 3.2-2 in the Technical Specifications.

ATTACHMENT 1 Page 17 of 18 PRIMARY CONTAINMENT ISOLATION VALVES

" Primary Containment' Isolation Valves"

1. Main steam isolation valves require that both solenoid pilots be de-energized to close l

valves. Accumulator air pressure plus spring force act together to close valves when both pilots are de energized. Voltage fat ture at only one pilot does not cause valve closure.  !

2. Primary containment spray and pressure suppression chamber (torus) cooling valves have interlocks that allow them to be senestly reopened after automatic closure. This provision permits containment spray, for high drywell pressure conditions, and/or pressure suppression chamber water cooling. Iten automatic signals are not present, these valves may be opened for test er operating convenience.
3. Testable check valves are designed for remote opening with zero differential pressure  ;

across the valve seat. The valves close on reverse flow even through the test switches  !

may be positioned for open. The valves open when pump pressure exceeds reactor pressure even though test switch may be posittened for close.

4. Control rod hydraulic lines are isolated by solenoid operated valves (normat insert and  !

withdraw), air operated valves (scree intet and outlet) and check valves (control rod 4 drive cooling water). The lines that extend outside the primary containment are small and terminate in a system designed to prevent outleakage (i.e., the scree discharge volume and associated instrument volumes). Solenoid operated valves are normally closed, but open on normal rod movement (insert and withdrew). Air operated valves normally closed, but open for control rod scree. Check valves are normally ope =i, but closed during control rod scree and insert. Att valve numbers shown are suffixed with control rod drive hydraulic control unit destgestles. For example, the complete designation for control rod 26-27 scree intet valve is 83A0v-126 (HCU-26-27.)

5. The standard nintaus closing rate for estauntic motor operated isoletton valves is based on a nominal line size of 12 inch. Uslag the standard closing rate,12 inch. line is isolated in 60 seconds.
6. Coincident signals 'G" and "T" open valves. Special interlocks permit testing these valves by manual switch except when asteentic signals are present.
7. Normal status positit,n of valve (open er closed) is the position during normat power operation of the reactor and is provided to this table for information only (see ' Normal Status" column.)
8. Signal *A' or 'P causes automatt, withdruset of TIP probe. When the probe is withdrawn, the belt valve automatically closes by eachaeltal action.
9. Reactor building ventitation exhaust high redietton signal "Z" is generated by two trip units. This requires one unit at high trip er both units at down scale (instrument fatture) trip, in order to initiate isolatlas.
10. Leak testing shall be acceeptished in accordance with Section 4.7.A.2.d in the Technical Specifications.
11. Valve 20A0V-95 opens during pump out of the drywell equipment sump. Automatic isolation signals "A" and 'F" override an open signal that might be present for sump pump out.

59 Rev. No. 5 Page 22_ of .-Rt

AW&OIRFM&DTSD TECH SPEC RELATED ISTS AND TABLESo AP-01.04 ATTACHMENT 1 Page 18 of 18 PRIMARY CONTAINMENT ISOLATION VALVES

" Primary Containment Isolation Valves"

12. Radiation monitors used for sampling lodine, particulate, and gaseous are as follown Radiation Monitors Sample 17-RM-101A Iodine 17-RM-101B 17-RM-102A Particulate 17-RM-1028 17-RM-103A Gaseous 17-RM-103B h 13. Isolation signals "A", 'F', and *Z" may be manually overridden by keytock switch on the Monitoring and Analysis Panet (MAP) located in the relay room.
14. Traversing In-core Probe (TIP) penetrations are isolated by a guide tube and valve assembly which includes a solenold operated batt valve and an explosive shear valve designed to sever and seal the TIP tubing and TIP detector helix.
15. The explosive shear valves are not normally actuated and require replacement parts and maintenance activity in order to open the valves following actuation.

W Rev. No.  ; Page 23 of 23

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 1 of 34 FIRE PROTECTIQN REQU_IREMENT_S 1.0 Intr _ o<1uction This attachment contains requirements for the Fire Protection Program formerly contained in the Technical Specifications.

Trensferral of these requirements to the FSAR is in accordance with the NRC guidance contained in Generic Letters 86-10 and 88-12. These requirements continue to be implemented by plant procedures. Certain terms used throughout this section are dsfined in Section 1.0 of the Technical Specifications and below.

Definition High Pressuru '"1*er Fire Protection Syste_za The High Pressure Water Fire Protection System consists oft a water source and pumps; and distribution system piping with associated post indicator valves (isolation valves). Such valves include the yard hydrant curb valves and the first valve ahead of the water flow alarm device on each sprinkler or water spray subsystem.

1.1 Technical Recuirements 1.2 Surveillance Recuirements 1.1.1 Gener_al Technical Requirement _s 1.2.1 General Surveillance Require _me_nts Apnlicability: Aeolicabili.ty:

Applies to the general technical requirements of Applies to the general surveillance requirements of Ssetion 1.1. Section 1.2.

Obiective Obiective:

To specify the general requirements applicable to each To specify the general requirements applicable to each technical requirement in Section 1.1. surveillance requirement in Section 1.2.

A. Technical Requirements and ACTION requirements shall A. Surveillance Requirements shall be applicable during be applicable during the OPERATIONAL CONDITIONS the OPERATIONAL CONDITIONS (modes) specified for (modes) specified for each Technical Requirement. individual Technical Requirement unless otherwise stated in the individual Surveillance Requirements.

B. Adherence to the requirements of the Technical B. Each surveillance Requirement shall be performed Requirement and associated ACTION within the within the specified surveillance interval with a specified time interval shall constitute compliance maximum allowable extension not to exceed 25 percent with the Technical Requirement. In the event the of the specified surveillance interval.

Technical Requirement is restored prior to expiration of the specified time interval, completion of the ACTION statement is not required.

Rev. No. Page 2 Y of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 2 of 34 FJ_RE PEQTECTION REQQIh""E 1.1.1 Continued 1.2.1 Continued C. In the event a Technical Requirement and/or C. Performance of a Surveillance Requirement within the associated ACTION requirements cannot be satisfied specified time interval shall constitute compliance because of circumstances in excess of those with OPERABILITY requirements for a Technical addressed in the Technical Requirement, the unit Requirement and associated ACTION statements unless shall be placed in COLD SHUTDOWN within the otherwise required by the Technical Requirement.

following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless corrective measures are Failure to perform a Surveillance Requirement within completed that permit operation under the the allowed surveillance interval, defined by permissible ACTION or until the reactor is placed in Surveillance Requirement 1.2.1.B, shall constitute an OPERATIONAL CONDITION (mode) in which the noncompliance with the OPERABILITY requirements for Technical Requirement is not applicable. Exceptions a Technical Requirement. The time limits of the to these requirements shall be stated in the ACTION requirements are applicable at the time it is individual Technical Requirements. identified that a Surveillance Requirement has not been performed. The ACTION requirements may be delayed up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> to permit the completion of the surveillance when the allowable outage limits of the ACTION requirements are less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

Surveillance requirements do not have to be performed on inoperable equipment.

D. Entry into an OPERATIONAL CONDITION (mode) or other D. Entry into an OPERATIONAL CONDITION (mode) shall not specified condition shall not be made when the be made unless the Surveillance Requirement (s) conditions for the Technical Requirement are not met associated with the Technical Requirement have been and the associated ACTION requires a shutdown if performed within the applicable surveillance they are not met within a specified time interval. interval or as otherwise specified. This provision Entry into an OPERATIONAL CONDITION (mode) or shall not prevent passage through or to Operational specified condition may be made in accordance with Modes as required to comply with ACTION ACTION requirements when conformance to them permits Requirements.

continued operation of the facility for an unlimited period of time. This provision shall not prevent passage through OPERATIONAL CONDITIONS (modes) required to comply with ACTION requirements.

Exceptions to these requirements are stated in the individual Technical Requirements.

R*.ev . No. Page 6 of 57

TECH SP'I.C RELATED REQUIREMENTS, LISTS AND TABLES

  • _AP-01.04 ATTACHMENT 2 Page 3 of 34 FIRE PROTECTION REQUIREMENT _H 1.1.1 Continued 1.2.1 Continued E. When a system, subsystem, train, component or device is determined to be inoperable solely because its emergency power source is inoperable,.or solely because its normal power source is inoperable, it may be considered OPERABLE for the purpose of satisfying the requirements of its applicable Limiting Condition for Operation, provided: (1) its corresponding normal or emergency power source is OPERABLE; and (2) all of its redundant system (s),

subsystem (s), train (s), component (s) and device (s) are OPERABLE, or likewise satisfy the requirements of this Technical Requirement. Unless both conditions (1) and (2) are satisfied, the unit shall be placed in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. This Technical Requirement is not applicable when in Cold shutdown or Refuel Mode.

a 5

Rev. No. Page 2S of 57

. , _ - .~ _ _ _ _ _ - _ _ _ _ _. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 4 of 34 FIRE PROTECTION REQIILREMENT_A

+

1.1.1 Rases 'f A. - This Technical Requirement states the applicability D. Continued -

of each Technical Requirement in terms of defined OPERATIONAL CONDITION (mode) and is provided to operation of the facility for an unlimited period of delineate specifically when each Technical time provides an acceptable level of safety for  !

Requirement is applicable. continued operation without the regard to the status I

! of the plant before or after an OPERATIONAL

.. B. This General Requirement defines those conditions CONDITION (mode) change. Therefore in this case, I

necessary to constitute compliance with the' terms of entry into an OPERATIONAL CONDITION (mode) or other an individual Technical Requirement and associated specified condition may be made in accordance with j ACTION requirement. the provisions of the ACTION requirements. The

  • provisions of this Technical Requirement should not,

, C. This General Requirement delineates the ACTION to be however, be interpreted as endorsing the failure to taken for circumstances not directly provided for in exercise good practice in restoring systems or

, the ACTION statemants and whose occurrence would components to OPERABLE status before startup.

violate the intent of the Technical Requirement. _

i Under the terms of Technical Requirement 1.1.C, the Exceptions to this provision may be made for a facility is to be placed in COLD SHUTDOWN within the limited number of Technical Requirements when following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. It is assumed that the unit is startup with inoperable equipment would not affect brought to the required OPERATIONAL CONDITION (mode) plant safety. These exceptions are stated in the within the required times by promptly initiating and ACTION statements of the appropriate Technical

carrying out the appropriate ACTION statement. Requirements.

D. This Technical Requirement provides that entry into E. This Technical Requirement delineates what an OPERABLE CONDITION (mode) must be made with (a) additional conditions must be satisfied to permit the full complement of required systems,' equipment operation to continue, consistent with the ACTION or components OPERABLE and (b) all other parameters statements for power sources, when a normal or as specified in the Technical Requirements being met emergency power source is not OPERABLE. It without regard for allowable deviations and out of specifically prohibits operation when one division service provisions contained in the ACTION is inoperable because its normal or emergency power statements. source'is inoperable and a system,. subsystem, train,-

  • component or device in another division is '

The intent of this provision is to insure that inoperable for another reason. -

facility. operation is not initiated with either .

'l

, required equipment or' systems inoperable or other The provisions of this Technical Requirement permit '

limits being exceeded. Compliance with ACTION the ACTION statements associated withi requirements that permit continued b

l Rsv.'No. :Page 2 F of 57-i

, ,, . , , ..# . ~ . . - ~ . , . _ , --_ _ _ _ _ _ _ _ _ _ _ .

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 5 of 34 I FI_RE PRQLECT_I_QN REQRREMERM 1.1.1 Bases - Continued E. Continued E. Continued individual systems, subsystems, trains, components ACTION statement provides a 7 day out-of-service or devices to be consistent with the ACTION time when both required offsite circuits are not statement of the associated electrical power source. OPERABLE. If the definition of OPERABLE were applied It allows operation to be governed by the time without consideration of Specification 3.0.E., all limits of the ACTION statement associated with the systems, subsystems, trains, components and devices Limiting Condition for Operation for the normal or supplied by the inoperable normal power sources, emergency power source, and not by the individual both of the offsite circuits, would also be ACTION statements for each system, subsystem, train, inoperable. This would dictate invoking the component or device that is determined to be applicable ACTION statements for each of the inoperable solely because of the inoperability of applicable LCOs. However, the provisions of its normal or emergency power source. Specification 3.0.E. permit the time limits for continued operation to be consistent with the ACTION For example, Specification 3.9.A. requires in part statement for the inoperable normal power sources that both emergency diesel generator systems be instead, provided the other specified conditions are l OPERABLE. The ACTION statement provides for a 7 day satisfied. In this case, this would mean that for out-of-service time when emergency diesel generator one division the emergency power source must be system A or B is not OPERABLE. If the definition of OPERABLE (as must be the components supplied by the OPERABLE were applied without consideration of emergency power source) and all redundant systems, Specification 3.0.E., all systems, subsystems, subsystems, trains, components and devices in the trains, components and devices supplied by the other division must be OPERABLE, or likewise satisfy inoperable emergency power source, diesel generator Specification 3.0.E. (i.e., be capable of performing system A or B, would also be inoperable. This would their design functions and have an emergency power dictate invoking the applicable ACTION statements source OPERABLE). In other words, both emergency for each of the applicable Limiting Conditions for power sources A and B must be OPERABLE and all Operation. However, the provisions of Specification redundant systems, subsystems, trains, components l 3.0.E. permit the time limits for continued and devices in both divisions must also be OPERABLE. I operation to be consistent with the ACTION statement If these conditions are not satisfied, shutdown is  ;

for the inoperable emergency diesel generator system required in accordance with this Technical '

instead, provided the other specified conditions are Requirement.

satisfied. If they are not satisfied, shutdown is required in accordance with this Technical In Cold Shutdown and Refuel Modes, Technical Requirement. Requirement 1.1.1.E. is not applicable, and thus the individual ACTION statement for each applicable As a further example, Specification 3.9.A. requires Technical Requirement in these OPERATIONAL in part that two ll5KV lines and reserve station CONDITIONS (modes) must be adhered to.

transformers be available. The R=v. No. Page N of 57

__ _- -a

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 6 of 34 EIRE PROTECT _I.Q_N REQU_IREMENTS 1.2.1 Bases A. This Surveillance Requirement provides that C. This Surveillance Requirement establishes the surveillance activities necessary to insure the failure to perform a Surveillance Requirement within Technical Requirements are met and will be performed the allowed surveillance interval, defined by the during the OPERATIONAL CONDITIONS (modes) for which provisions of Surveillance Requirement 1.2.1.B, as a the Technical Requirements are applicable. condition that constitutes a failure to meet the Provisions for additional surveillance activities to OPERABILITY requirements for a Technical be performed without regard to the applicable Requirement. Under the provisions of this OPERATIONAL CONDITIONS (modes) are provided in the Surveillance Requirement, systems and components are individual Surveillance Requirements. assumed to be OPERABLE when Surveillance Requirements have been satisfactorily performed B. Surveillance Requirement 1.2.1.B establishes the within the specified time interval. However, limit for which the specified time interval for nothing in this provision is to be construed as Surveillance Requirements may be extended. It implying that systems or components are OPERABLE permits an allowable extension of the normal when they are found or known to be inoperable surveillance interval to facilitate surveillance although still meeting the Surveillance scheduling and consideration of plant operating Requirements. This General Requirement also conditions that may not be suitable for conducting clarifies that the ACTION requirements are l the surveillance (e.g., transient conditions or applicable when Surveillance Requirements have not other ongoing surveillance or maintenance been completed within the allowed surveillance activities). It also provides flexibility to interval and that the time limits of the ACTION accommodate the length of a fuel cycle for requirements apply from the point in time it is surveillances that are performed at each refueling identified that a surveillance has not been outage and are specified with an 18 month performed and not at the time that the allowed surveillance interval. It is not intended that this surveillance was exceeded. Completion of the provision be used repeatedly as a convenience to Surveillance Requirement within the allowable outage i

extend surveillance intervals beyond that specified time limits of the ACTION requirements restores

for surveillences that are not performed during compliance with the requirements of Surveillance
refueling outages. The limitation of this Requirement 1.2.1.C. However, this does not negate requirement is based on engineering judgement and the fact that the failure to have performed the the recognition that the most probable result of any surveillance within the allowed surveillance l

particular surveillance being performed is the interval, defined by the provisions of Surveillance l verification of conformance with the Surveillance Requirement 1. 2 .1. B, was a violation of the Requirements. The limit on extension of the normal OPERABILITY requirements of a Technical Requirement surveillance interval ensures that the reliability that may be subject to enforcement action.

confirmed by surveillance activities is not significantly reduced below that obtained from the specified surveillance interval.

l Rsv. No. Page 2 9 of 57 l

l

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 7 of 34 FIRE PROTECTION _REQIIIEEMENT_S
1. 2.1 Ea_s.es - Continued C. Continued C. Continued If the allowable outage time limits of the ACTION Surveillance Requirements do not have to be requirements are less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or a shutdown is performed on inoperable equipment because the ACTION required to comply with ACTION requirements, a requirements define the remedial measures that 24-hour allowance is provided to permit a delay in apply. However, the Surveillance Requirements have implementing the ACTION requirements. This provides to be met to demonstrate that inoperable equipment an adequate time limit to complete Surveillance has been restored to OPERABLE status.

Requirements that have not been performed. The purpose of this allowance is to permit the D. This Surveillance Requirement establishes the completion of a surveillance before a shutdown is requirement that all applicable surveillances must required to ccmply with ACTION requirements or be met before entry into an OPERATIONAL CONDITION or before other remedial measures would be required other condition of operation specified in the that may preclude completion of a surveillance. The Applicability statement. The purpose of this basis for this allowance includes consideration for General Requirement is to ensure that system and plant conditions, adequate planning, availability of component OPERABILITY requirements or parameter personnel, the time required to perform the limits are met before entry into an OPERATIONAL surveillance and the safety significance of the CONDITION or other specified condition associated delay in completing the required surveillance. This with plant shutdown as well as startup.

provision also provides a time limit for the completion of Surireillance Requirements that become Under the provisions of this Surveillance applicable as a consequence cf OPERATIONAL CONDITION Requirement, the applicable Surveillance (mode) changes imposed by ACTION requirements and Requirements must be performed within the specified for completing Surveillance Requirements that are surveillance interval to ensure that the Technical applicable when an exception to the requirements of Requirements are met during initial plant startup or Surveillance Requirement 1.2.1.C is allowed. If a following a plant outage.

surveillance is not completed within the 24-hour allowance, the time limits of the ACTION When a shutdown is required to comply with ACTION requirements are applicable at that time. When a requirements, the provi:sions of this Surveillance surveillance is performed within the 24-hour Requirement do not apply because this would delay allowance and the Surveillance Requirements are not placing the facility in a lower CONDITION of met, the time limits of the ACTION requirements are operation applicable at the time the surveillance is terminated.

i R$v. No. Page 30 of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 8 of 34 FIRE PROTECTION __REQtJl_REMENTS 1.1.2 Fire Protection Systems Technical Requirement;s 1.2.2 Eire Protection Systems Surveilla_ rice Aequir_ement_s Amplicability: Aeolicability:

Applies to the Operational Status of the Fire Protection Applies to the Surveillance of the Fire Protection Systems. Systems.

Ob_icctive:

To assure operability of the Fire Protection Systems. O_ biective r To verify the operability of the Fire Protection Systems.

A. High Pressure Water Fire Protection SysteLa A. High_Eressu_te Water Fire Protection System

1. a. Both high pressure water fire protection pumps 1. High pressure water fire protection system testing and associated automatic and manual initiation logic shall be operable and aligned to the Item Execuene_y high pressure water fire header.
a. High pressure Once/ week
b. The high pressure water fire protection system water fire protection shall be operable with an operable flow path system pressure check.

capable of taking suction from the lake and transferring the water through distribution b. The each pump,on a once/ month piping with operable sectionalizing control or STAGGERED TEST BASIS, isolation valves to the yard hydrant curb by starting and operating valves and the first valve ahead of the water it for at least 20 minutes flow alarm device on each sprinkler, or spray on recirculating flow.

system riser required to be operable per Technical Requirement 1.1.2.B and to each hose c. Valve operational Once/12 months station riser isolation valve required to be test.

operable per Technical Requirement 1.1.2.D.

d. System flush. Once/6 months Rev. No. Page 3/ of 57

TECH SPEC RELATED REQUIREMENTS,. LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 9 of 34 FIRE PROTECTI_QN REOUIREMENTE

-1.1.2.A Continued 1.2.2.A Continued

c. With one pump and/or associated automatic and LtJm; Freauency manual initiation logic is inoperable, restore the inoperable equipment to operable e. Functional test Once/18 months status within 7 days or, in lieu of any other including:

report required by Specification 6.9.A, submit a Special Report to the Commission, within the 1. Simulated automatic next 30 days outlining the plans and actuation of each pump, procedures to be used to provide for the loss of redundancy in this system. 2. verifying that each automatic valve in the

d. With high pressure water fire protection flow path actuates to system otherwise inoperable: its correct position,
1. Establish a backup fire suppression 3. verifying that each water system within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and pump develop at least 2500 gpm at a pressure
2. Submit a Special Reports of 125 psig, and a) By telephone within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, 4. verifying that each pump starts (at greater than or b) Confirm by telegraph, mailgram or equal to 105 psig for the facsimile transmission no later electric pump and greater than the first working day- than or equal to 95 psig following the event, and for the diesel driven pump) to maintain the fire suppression water system pressure.

1 R v. No. Page 3 % of 57

L_

TECH SPEC RELATED REQUIREMENTS, LISTS AND' TABLES

ATTACHMENT 2 Page 10 of-34 EIEE PROTECTION RXQUIREMENT_H 1.1.2.A- Continued 1.2.2.A Continued ,

c) In writing within 14 days Item Frequen9I '

following the event, outlining the actions taken, the cause of the f. System flow test in once/3 years inoperability and the plans and accordance with schedule for restoring the system Section 11, Chapter 5 to operable status. of the Fire Protection Handbook, 14th Edition,  ;

3.. If 1. above cannot be fulfilled, place published by the National '

the reactor.in Hot Standby within Fire Protection Association.

six.(6) hours and in Cold shutdown within the following thirty (30) hours. g. Each valve in the flow Once/ Month path by verifying it is in its correct position.

h. Fire pump diesel engine Once/ Month by verifying the fuel i storage tank centains at least 172 gallons ,

of fuel.

L i

R=v. No. Page U of 57

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TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

ATTACHMENT 2 Page 11 of 34 i FIRE PROTECTION REORIEEMENTS 1.1.2.A Continued 1.2.2.A Continued Item Frecuenc_y

i. Diesel fuel from each once/ Quarter tank obtained in accordance ,

with ASTM-D270-65 is within the acceptable limits for quality as per the following:

Flash Point *F 125*F min.

Pour Point - *F 10*F max.

  • Water & Sediment 0.05% max.

Ash 0.01% max.

Distillation 90% Point 540 min.-

Viscosity (SSU) 9 10 0*F 40 max.

Sulfur 1% max.

Copper Strip Corrosion No. 3 max.

Cetane # 35 min.

J. Fire pump diesel engine Once/18 months by inspection during shutdown in accordance with procedures prepared in conjunction with manufacturers reccamendations and verifying the diesel, starts from ambient conditions l on the auto start signal and operates for 220 minutes while loaded with the-fire pump.

l R v.'No. Page N of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 12 of 34 FlIR_R PROTECTI_ON REOUIREMENTE 1.1.2.A Continued 1.2.2.A Continued Item Etequency
k. The fire pump diesel once/ Week starting 24 volt battery bank and charger by verifying that the -

electrolyte level of each battery is above the plates and the overall battery voltage is 24 volts.

1. The diesel starting Once/ Quarter 24 volt battery by verifying that the specific gravity is appropriate for continued service of the battery.
m. The diesel starter once/18 Months 24 volt battery by verifying that the batteries, cell plates and battery racks show no visual indication of physical damage or abnormal deterioration and the battery-to-battery and terminal connections are clean, tight, free of corrosion, and coated with anti-corrosion material.

R v. No. Page 6 of 57

, -TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 13 of 34 FIRE PRQTECTION REOUIREMENTS 1.1.2 continued 1.2.2 continued B. Water Sorav and Sprinkler Systems B. Water Sorav and Sprinkler Systems
l. -a. The water. spray and/or sprinkler in the areas 1. The water spray'and/or sprinkler systems are tested F listed in Table 1 shall be operable except as as listed in Table 2.

specified below.

b. From the time that water spray and/or' sprinkler protection for any areas listed in Table 1 is made.or found inoperable, backup fire suppression equipment and a continuous fire watch will be established for the t

unprotected area within one hour.

2. If the water spray and/or sprinkler protection

. system for any area listed in Table 1 cannot be restored to an operable status within 14 days, a written report to the Conanission outlining the action taken,_the cause of inoperability, and plans and schedule to restoring the system to an operable status shall be prepared and submitted within 30

-days.

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-f Rev. No. Page 36 of 57

L TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 14 of 34 FIRE PROTECTION REQUIREMENTE C. CartLon Dioxide Systems C. Carbon g oxide Systems
1. a. The CO, protection in the areas listed in 1. The Co, systems are tested as listed in Table 4.

Table 3 shall be operable except as specified below. i

b. From the-time that CO2 protection for any areas listed in Table 3 is made or found inoperable, backup fire suppression equipment and a continuous fire watch will be established for the unprotected area (s) within ,

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

2. If the CO, protection for the areas listed in Table 3 cannot be restored to an operable status within 14 days, a written report to the Cnmrni salon outlining the action taken, the cause of inoperability, and  ;

plans and schedule to restore the system to an operable status shall be prepared and submitted within 30 days.

{

-Rev. No. Page N of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 15 of 34 FlRE_PEQTECTIQ!LEEOUIEF20i2IT_S 1.1.2 Continued 1.2.2 Continued D. Manu_al Fire Hose Stations D. Mariu_al Fire Hose Stati.on.s j

{

l. a. The manual hose stations listed in Table 5 1. The manual fire hose stations are inspected as {

shall be operable except as specified below: listed in Table 6. {

b. From and after the date that any of the manual fire hose stations listed in Table 5 is made or found to be inoperable, additional hose lengths shall be added to adjacent operable hose stations such that the entire area of protection is maintained within one hour.

l l E. Eire Protection Systejns Smoke and Heat Detectors E. Fire Protection Systems Smo.Ae and Heat De l ectou

1. a. Fire protection systems smoke and/or heat 1. A channel functional test of smoke and heat detectors in each protected area as designated detectors and associated circuitry shall be in Tables 1 and 3 shall be operable except as performed every 6 months. This test includes specified belows operability of valves associated with the detectors and verifying that the automatic valves in the flow i
b. From and after the date that more than one path actuate to their correct positions.

smoke and/or heat detector in each protected area is found or made inoperable, within one hour an hourly patrolling fire watch shall be established.

2. If the fire protection systems smoke and/or heat detectors in Tables 1 and 3 cannot be restored to an operable status within 14 days, a written report to the Commission outlining tl.e action taken, the cause of inoperability and plans and schedule for restoring the detectors to an operable status shall be prepared and submitted within 30 days.

R v. No. Page 28 of 57

1 TECH SPEC RELATED REQUIREMENTS,' LISTS AND TABLES

. FLRR_P_ROTECTION REOUIRELG;NT_S

-1.1.2 continued 1.2.2 Continued F. Fire Barrier Penetration Sea 3s F. Fire Barrier Penet; ration Seals

1. All fire barrier penetrations, including cable 1. All fire barrier penetration seals for each penetration barriers, fire doors and fire dampers, protected area s?.all be visually inspected once per in fire zone boundaries protecting safety related operating cycle co verify functional integrity. For areas shall be functional. those fire barrier penetrations that are not in the

' as-designed condition, an evaluation shall be

2. With one or more of the required fire barrier performed to show that the modification has not penetrations non-functional, within one hour degraded the fire rating of the fire barrier establish a continuous fire watch on at least one penetration.

side of the affected penetration or verify the ,.

operability of fire detectors on at least one side 2. Any repair of fire barrier penetration seals shall of the non-functional fire barrier and establish an be followed by a visual inspection.

hourly fire watch patrol. Restore the non-functional fire barrier penetration (s) to functional status within 7 days or, in lieu of any other report required by Specification 6.9.A, prepare and submit a Special Report to the Commission within 30 days outlining the. action taken, the cause of the non-functional penetration and plans and schedule for restoring the fire barrier penetration (s) to functional status.

Rev. No. Page'3h of 57

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TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 17 of 34 EIRE PROTECTION REQUI_REMEIRS 1.1.2 and 1.2.2 Bases Tha Fire Protection System Technical And Surveillance A. Continued Riquirements provide pre-established minimum levels of opsrability to assure adequate fire protection during any Prassure Maintenance subsystem checks, valve operating condition including a design basis accident or position checks, system flushes and comprehensive ccfo shutdown earthquake. pump and system flow and/or performance tests including logic and starting subsystem tests provide A. The high pressure water fire protection system is for the early detection and correction of component supplied by redundant vertical turbine pumps, one failures thus ensuring high levels of operability.

diesel driven and one electric motor driven, each design rated 2500 gym at 125 psig discharge B. Safety related equipment areas protected by water pressure. Both pumps take suction from the plant spray or sprinklers are listed in Table 1. Whenever intake cooling water structures from Lake Ontario. any of the protected areas, spray or sprinklers are The high pressure water fire protection header is inoperable, continuous fire detection and backup normally maintained at greater than 115 psig by a fire protection equipment is available in the area pressure maintenance subsystem. If pressure where the water spray and/or sprinkler protection decreases, the fire pumps are automatically started was lost.

by their initiation logic to maintain the fire protection system header pressure. Each pump, Table 2 specifies tests and inspections to detect together with its manual and automatic initiation nozzle blockage or breakage, to verify header logic combined makes up a redundant high pressure integrity, and to ensure valve operability.

water fire pump. Surveillance for flow alarm check valves in wet pipe sprinkler systems is performed by providing A third fire pump, diesel-driven, has been installed sufficient flow through the valve to activate the and is set to automatically actuate upon decreasing alarm. Full cycling is not required since the flow pressure after the actuation of the first two fire alarm check valves are not designed to latch open.

pumps. No credit is taken for this pump in any analyses and the requirements of Sections 1.1.2 and 1.2.2 do not apply.

rov. No. Page 1 0_ of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 18 of 34 FIRE PROTECTION _REQlTIREMEMTJ 1.1.2 and 1.2.2 Bases - Continued C. The carbon dioxide systems provide total flood D. Manual hose stations provide backup fire protection protection for eight different safety related areas throughout the Plant. Those hose stations that are of the plant from either a 3 ton or 10 ton storage in or near areas with safety related equipment are unit as indicated in Table 3. Both CO, storage units listed in Table 5. Hose station location and hose are equipped with mechanical refrigeration units to length selection provides the capability of reaching maintain the storage tank content at O*F with a any fire in a safety related area with the hose resultant pressure of 300 psig. Automatic smoke and stream. When any of the hose stations listed in heat detectors are provided in the CO, protected Table 5 is inoperable, providing additional hose areas and initiation is automatic and/or manual as lengths from other operable hose stations assures indicated in Table 3. For any area in which the co m maintenance of this capability. Periodic inspection protection is made or found to be inoperable, and tests are in accordance with NFPA Code continuous fire detection is available and one or guidelines and assures prevention, detection and more large wheeled CO 2 fire extinguisher is also correction of hose, nozzle, valve and/or gasket available for each area in which protection was damage or deterioration to maintain high levels of lost. operability.

Weekly checks of storage tank pressure and level E. Early fire detection and fire fighting activity is verify proper operation of the tank refrigeration essential to ensuring that any fire will result in units and availability of sufficient volume of CO, minimum damage to safety related equipment. Since to extinguish a fire in any of the protected areas. each area monitored utilizes a number of smoke and/or heat detectors when more than one detector is Performance of the periodic tests and inspections inoperable, early fire detection is assured by listed in Table 4 are in accordance with NFPA-12, establishing a patrolling fire watch which check the 1973, will verify the integrity of system nozzles area where the detectors are inoperable at least and distribution headers as well as detect and hourly. Wet pipe flow alarms are not depended upon removn any accumulation of rust or scale. The use for fire detaction. Fire detection surveillance of " puff test" rather than full flow tests will testing is therefore not required for wet pipe flow demonstrate proper valva ;sration without the alarms by the surveillance Requirement.

attenda.nt potential equi pent and personnel hazards associated with fall flow tests.

Rav. No. Page 9/ of 57

TECH ~ SPEC RELATED REQUIREMENTS, LISTS AND TABLES * .AP-01.04' ATTACHMENT 2 Page 19 of 34 FIRE PROTECTION REOUI M E 1.1.2 and 1.2.2 Bases - Continued E. Continued F. Continued Testing of smoke and heat detectors and associated During periods of time when the barriers are not circuitry every 6 months, in accordance with functional, either, 1) a continuous fire watch is manufacturers and NFPA 72E-1974 recomunendations required to be maintained in the vicinity of the ensures a high level of operability. affected barrier, or 2) the fire detectors on at least one side of the affected barrier must be F. The functional integrity of the fire barrier verified. operable and a hourly fire watch patrol penetrations ensure that fire will be confined or established until the barrier is restored to 4 adequately retarded from-spreading to adjacent functional status.

portion of the facility. This design feature minimizes the possibility of a single fire rapidly involving several area.s of the facility prior to detection and extinguishment. The fire barrier penetrations are a passive element in the facility fire protection program and are subject to periodic inspections.

The barrier penetrations, including cable penetration barriers, fire doors and dampers are considered functional when the visually observed condition is the same as the as-designed condition.

Rav. No.

Page T2 of 57

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TECH SPEC RELATED REQUIREMENTS, LIST 5'AND TABLES *' AP-01.04 ATTACHMENT 2 Page 20 of 34-F_I_RE PROTECTIQN REQUIREMENTH 1.3 Administrative Recuirements 1.3.1

( -A fire brigade of five (5) or more members shall be maintained'on site at all times. This excludes two (2) members of the-minimum shift crew necessarylfor safe shutdown and any personnel required for other essential functions during a fire emergency.

1.3.2 1 In the' event of illness or unexpected absence, up to two (2) hours is' allowed to restore the fire brigade to the minimum complement.

1.3.3

-Fire brigade training shall meet or exceed the requirements of NFPA 27-1975, except for Fire Brigade training sessions which shall be held at least quarterly.

( ;-

Rev. No. Page U ' of 57 L _. - _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___________ ___

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 21 of 34 EIRE PROTECTION REOUIREMELLTR TABLE 1 WATER SPRAY / SPRINKLER PROTECTED AREAS AREA FIRE DETECTION TYPE PROTECTION"' TYPE INITIATION
1) West Cable Ionization Device Fusible Link Sprinklers / Automatic Tunnel Frangible Element Nozzles
2) East Cable Ionization Device Fusible Link Sprinklers / Automatic Tunnel Frangible Element Nozzles
3) Recirculation Electric Heat Fusible Link Sprinklers Automatic / Manual MG Room Activated Device
4) Emergency Electric Heat Fusible Link Sprinklers Automatic / Manual Diesels"' Activated Device
5) HPCI Electric Heat Water Spray Manual Activated Device
6) RCIC Electric Heat Water Spray Manual Activated Device .
7) Standby Gas Electric Heat Water Spray Manual Treatment Trains"' Activated Device
8) west Diesel Fire Ionization Device Fusible Link Sprinklers Automatic Pump Room
9) Battery Room Ionization Device Fusible Link Sprinklers Automatic Corridor NOTES FOR TABLE 1
1. Each of two (2) Emergency Diesel Generator Systems is a separate protected area, each system contains two (2) separate rooms.
2. Each of two (2) Standby Gas Treatment trains is a separate area.
3. All areas are also protected by fire hoses and portable dry chemical and/or CO2 fire extinguishers.

Rav. No. Page YM of 57

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' TECH. SPEC F. ELATED REQUIREMENTS, LISTS AND TABL3S* AP-01.04 ATTACHMENT 2 Page 22 of 34 FIRE PROTECTION REQUI_REMENTE t

TABLE 2 WATER SPRAY / SPRINKLER SYSTEM TESTS CYCLING SPRAY NOZZLE HEADER INTEGRITY NOZZLE AIR AREA EACH VALVE INSPECTION INSPECTION FLOW TEST

1) West Cable Once/6 Months'" N/A Once/1.5 Years N/A Tunnel
2) East Cable Once/6 Months'" N/A Once/1.5 Years N/A 4

Tunnel

3) Recirculation Once/6 Months N/A Once/1.5 Years N/A MG Room

, 4) Emergency Once/6 Months N/A Once/1.5 Years N/A Diesel Rooms

5) HPCI Once/6 Months Once/1.5 Years Once/1.5 Years Once/3 Years
6) RCIC Once/6 Months Once/1.5 Years Once/1.5 Years once/3 Years
7) Standby Gas once/6 Months Once/1.5 Years once/1.5 Years Once/3 Years Treatment Trains i I
8) West Diesel Fire None N/A Once/1.5 Years N/A Pump' Room j

^

.9) Battery Room Once/6 Months'" N/A Once/1.5 Years N/A Corridor NOTES FOR TABLE 2 i 1. These are wet pipe systems which contain flow alarm check valves. The surveillance for flow alarm check valves is ,

performed by providing sufficient flow through the valve to actuate the alarm. Full valve cycling is not required. I l

l Rsv. No. Page 6 of 57' t

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 23 of 34 FIBE PROTECTION REQUIREMERT_S TABLE 3 CARBON DIOXIDE PROTECTED AREAS AREA CO2 SOURCE FIRE DETECTION INITIATION
1) Cable Spreading 10 Ton Unit Ionization and Electric Automatic / Manual Room > 280 psig Heat Activated Device

> 45% capacity

2) Relay Room 10 Ton Unit Ionization and Electric Manual

> 280 psig Heat Activated Device

> 45% capacity

3) Relay Room to 10 Ton Unit Ionization and Electric Automatic / Manual Reactor Building > 280 psig Heat Activated Device Cable Tunnel-South > 45% capacity
4) Relay Room to 10 Ton Unit Ionization and Electric Automatic / Manual Reactor Building > 280 psig Heat Activated Device Cable Tunnel-North > 454 capacity
5) Switchgear Room - 10 Ton Unit Ionization and Electric Automatic / Manual West > 280 psig Heat Activated Device

> 45% capacity

6) Switchgear Room - 10 Ton Unit Ionization and Electric Automatic / Manual East > 280 psig Heat Activated Device

> 4 5*4 capacity

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7) Diesel Generator 3 Ton Unit Ionization and Electric Automatic / Manual Switchgear Room - > 280 psig Heat Activated Device South > 45% capacity I
8) Diesel Generator 3 Ton Unit Ionization and Electric Automatic / Manual Switchgear Room - > 280 psig Heat Activated Device North > 45% capacity NOTES FOR TABLE 3
1. All areas are also protected by fire hoses and portable dry and/or Co, fire extinguishers.

l Rav. No. Page 94 of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 24 of 34 F_ IRE _ P_RQTECTIDN_RE QHIEJ!tMENTS TABLE 4 CARBON DIOXIDE SYSTEM TESTS INSTRUMENT INSTRUMENT HEADER AND NOZZLE SIMULATED AUTOMATIC AREA CHECK CALIBRATION INSPECTION & MANUAL INITIATIONm
1) 10 Ton CO 2 Storage Unit once/ Week Once/ Year N/A N/A Level & Pressure
2) 3 Ton CO, Storage Unit once/ Week Once/ Year N/A N/A Level & Pressure
3) Cable Spreading Room N/A N/A Once/1.5 Years once/1.5 Years
4) Relay Room N/A N/A Once/1.5 Years Once/1.5 Yeara m
5) Relay Roam to Reactor Building N/A N/A Once/1.5 Years Once/1.5 Years Cable Tunnel - South
6) Relay Room to Reactor Building N/A N/A Once/1.5 Years Once/1.5 Years Cable Tunnel - North
7) Switchgear Room - West N/A N/A Once/1.5 Years Once/1.5 Years
8) Switchgear Room - East N/A N/A Once/1.5 Years once/1.5 Years
9) Diesel Generator N/A N/A Once/1.5 Years once/1.5 Years Switchgear Room - South
10) Diesel Generator N/A N/A Once/1.5 Years Once/1.5 Years Switchgear Poom - North NOTES FOR TABLE 4
1) Simulated automatic and manual initiation tests will be "puf f tests" and includes actuation of system valves and associated ventilation dampers.
2) Manual Test only.

R?iv. No. Page b of 57

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- TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 25 of 34 FIRE PRQIRCTION REOUIREMENTS TABLE 5 MANUAL FIRE HOSE STATIONS STATION NUMBER LOCATION HOSE STATION VALVE NUMBER 1 Reactor Building (Y-1) 264 Elevation 369 South East Curner Near Elevator 2 Reactor Building (A-2) 263 Elevation 369 South West Corner 3 Reactor Building (P-6) 262 Elevation 369 North West Corner 4 Reactor Building (W-6) 261 Elevation 369 North East Corner 5 Reactor Building (Y-6) 260 Elevation 344 North East Corner 6 Reactor Building (P-6) 259 Elevation 344 o North West Corner 7 Reactor Building-(A-2) 258  !

Elevation 344 South West Corner 8 Reactor Building (Y-1) 257 Elevation 344 South East Corner 9 Reactor Building (Y-1) 256 Elevation 326 South East Corner Rnv. No. Page I8 of 57 s . . . _. _ . _ - . . . . . _ _

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 26 of 34 E_ IRE PRQTECTIQN_REQUI_REMENTS TABLE 5 MANUAL FIRE HOSE STATIONS STATION NUMBER LOCATION HOSE STATION VALVE h M ER 10 Reactor Building (P-1) 255 Elevation 326 South West Corner 11 Reactor Building (P-6) 254 Elevation 326 North West Corner 12 Reactor Building (Y-6) 253 Elevation 326 North East Corner 13 Reactor Building (P-6) 251 Elevation 300 North West Corner 14 Reactor Building (P-1) 250 Elevation 300 South West Corner 15 Reactor Building (Y-1) 249 Elevation 300 i South East Corner 16 Reactor Building (Y-6) 252 Elevation 300 North East Corner 17 Reactor Building (D-7) 248 Elevation 272 North East Corner 18 Reactor Building (Y-1) 247 Elevation 272 South East Corner Rav. No. Page 47 of 57

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TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 27 of 34 FlRE PROTECTION _ERQUIREMENTE TABLE 5 MANUAL FIRE HOSE STATIONS STATION NUMBER LOCATION HOSE STATION VALVE hTMBER 19 Reactor Building (A-6) 246 Elevation 272 North West Corner 20 Reactor Building (P-1) 244 Elevation 272 South West Corner 21 Reactor Building (P-1) 243 Elevation 227 West Crescent Area 22 Reactor Building (Y-1) 242 Elevation 227 East Crescent Area 23 Standby Gas Treatment Room 265 Elevation 272 Scuth Wall 24 Auxiliary Boiler Room (D-9) 240 Elevation 272 Near Entrance 25 Auxiliary Boiler Room (G-8) 241 Elevation 272 East Wall 26 Administration Building (Z-10) 269 Elevation 272 Hall Opposite Cable Room Door 27 Administration Building (X-11) 236 Elevation 272 Opposite Elevator Rsv. No. Page OO of 57 W

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 28 of 34 F_I_RE PROTEXTION REQUlREMENTS TABLE 5 MANUAL FIRE HOSE STATIONS STATION NUMBER LOCATION HOSE STATION VALVE NUMBER 28 Administration Building (S-ll) 238 Elevation 286

. Hall Outside Lunch Room 29 Administration Building (S-ll) 239 Elevation 300 Opposite Elevator 30 Turbine Building (B-19) 226 Elevation 272 Near Electric Bay North Doors 31- Turbine Building (B-16) 267

' Elevation 272 Between SJAE re Recombiner 32 Turbine Building (Y-12) 234 Elevation 272 Near Stairwell to E.H.C.

33 Turbine Building (P-13) 235 Elevation 272 Near Electric Bay South Doors 34 Turbine Building (E-13) 220 Elevation 292 East of Panel HV-1 L 35 Turbine Building (c-12) 215 Elevation 300 Entrance to-Administration Building 36 Screen House (B-24) 209 Elevation 255 West - Near Traveling Screen A Rev. No. Page f/ of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 29 of 34 FIRE PROTERIQ1LAEQU_IEEbHLNTH TABLE 5 MANUAL FIRE HOSE STATIONS STATION NUMBER LOCATION HOSE STATION VALVE NUMBER 37 RHR/ESW Pump Room (B-26) 208 Elevation 255 West Side - Near Electric Fire Pump Controller 38 Screen House (Be-28) 207 Elevation 260 North - Near Circulating Water Discharge Gates 39 Screen House (Bh-24) 211 Elevation 260 East - Near City Water Oank 40 Screen House (Ba-26) 206 Elevation 272 West Side Between Panels HV-llA & B Rev. No. Page f 2 of 57 m

4 TECH SPEC'RELATED REQUIREMENTS, LISTS AND' TABLES

  • AP-01.04 ATTACHMENT 2 Page 30 of 34 FIRE PRQIECTION REQUIREMENTS TABLE 6 MANUAL FIRE HOSE STATION TESTS STATION LOCATION HOSE VALVE / HOSE / GASKET FLOW /

NUMBER STATION NOZZLE INSPECTION / HYDROSTATIC VALVE INSPECTION HOSE RERACK TEST

  • NUMBER 1 Reactor Building (Y-1) 264 Once/ Month Once/1.5 Years once/3 Years Elevation 369 South East Corner Near Elevator

, 2 Reactor Building (A-2) 263 Once/ Month once/1.5 Years once/3 Years Elevation 369 South West Corner 3 Reactor Building (P-6) 262 Once/ Month once/1.5 Years Once/3 Years Elevation 369 North West Corner 4 Reactor Building (W-6) 261 Once/ Month once/1.5 Years once/3 Years Elevation 369 North East Corner 5 Reactor Building (Y-6) 260 Once/ Month once/1.5 Years once/3 Years Elevation 344 I North East Corner 6 Reactor Building (P-6) 259 Once/ Month Once/1.5 Years once/3 Years Elevation 344-North West Corner 7 Reactor Building (A-2) 258 Once/ Month once/1.5 Years once/3 Years Elevatiou 344 South West Corner 8 Reactor Building (Y-1) 257 Once/ Month Once/1.5 Years once/3 Years Elevation 344 South East Corner 9 Reactor Building.(Y-1) 256- Once/ Month. Once/1.5 Years -Once/3 Years Elevation 326 South East Corner Rsv. No. Page N of 57

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TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 31 of 34 EIER_P_EQT_RCI; TON REQUIREMElqTS TABLE 6 MANUAL FIRE HOSE STATION TESTS STATION LOCATION HOSE VALVE / HOSE / GASKET FLOW /

NUMBER STATION NOZZLE INSPECTION / HYDROSTATIC VALVE INSPECTION HOSE RERACK TEST"'

NUMBER 10 Reactor Building (P-1) 255 Once/ Month once/1.5 Years once/3 Years Elevation 326 South West Corner 11 Reactor Building (P-6) 254 Once/ Month once/1.5 Years once/3 Years Elevation 326 North West Corner 12 Reactor Building (Y-6) 253 Once/ Month Once/1.5 Years Once/3 Years Elevation 326 North East Corner 13 Reactor Building (P-6) 251 Once/ Month once/1.5 Years once/3 Years Elevation 300 North West Corner 14 Reactor Building (P-1) 250 Once/ Month once/1.5 Years Once/3 Years Elevation 300 South West Corner 15 Reactor Building (Y-1) 249 Once/ Month once/1.5 Years Once/3 Years Elevation 300-South East Corner 16 Reactor Building (Y-6) 252 Once/ Month once/1.5 Years once/3 Years Elevation 300 North East Corner 17 Reactor Building (D-7) 248 Once/ Month Once/1.5 Years once/3 Years Elevation 272 North East Corner 18 Reactor Building (Y-1) -247 Once/ Month once/1.5 Years Once/3 Years Elevation 272 South East Corner Rsv. No. Page 87 of 57

TECH 3PEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 32 of 34 FIRE _PRQIECTIQH_ REQUIREMENTS TABLE 6 MANUAL FIRE HOSE STATION TESTS STATION LOCATION HOSE VALVE / HOSE / GASKET FLOW /

NUMBER STATION NOZZLE INSPECTION / HYDROSTATIC VALVE INSPECTION HOSE RERACK TEST

  • NUMEER 19 Reactor Building (A-6) 246 Once/ Month once/1.5 Years Once/3 Years Elevation 272 North West Corner 20 Reactor Building (P-1) 244 Once/ Month Once/1.5 Years Once/3 Years Elevation 272 South West Corner 31 Reactor Building (P-1) 243 Once/ Month once/1.5 Years once/3 Years Elevation 227 West Crescent Area 22 Reactor Building (Y-1) 242 Once/ Month once/1.5 Years Once/3 Years Elevation 227 East Crescent Area 23 Standby Gas Treatment Room 265- Once/ Month Once/1.5 Years Once/3 Years Elevation 272 South Wall 24 Auxiliary Boiler Room (D-9) 240 Once/ Month Once/1.5 Years Once/3 Years Elevation 272 Near Entrance 25 Auxiliary Boiler Room (G-8) 241 Once/ Month once/1.5 Years Once/3 Years Elevation 272 East Wall 26 Administration Building (Z-10) 269 Once/ Month Once/1.5 Years Once/3 Years Elevation 272 Hall Opposite Cable Room Door 27 Administration Building (X-11) 236 Once/ Month once/1.5 Years Once/? Years Elevation 272 Opposite Elevator Rev. No. Page 6of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 33 of 34 F_IER_ PROTECTION _EEQUlREMENTS TABLE 6 MANUAL FIRE HOSE STATION TESTS '

STATION LOCATION HOSS VALVE / HOSE / GASKET FLOW /

NUMBER STATION NOZZLE INSPECTION / HYDROSTATIC VALVE INSPECTION HOSE RERACK TEST *'

NUMBER 28 Administration Building (S-11) 238 Once/ Month once/1.5 Years Once/3 Years Elevation 286 Hall Outside Lunch Room 29 Administration Building (S-11) 239 Once/ Month once/1.5 Years Once/3 Years Elevation 300 Opposite Elevator 30 Turbine Building'(B-19) 226 Once/ Month once/1.5 Years Once/3 Years Elevation 272 Near. Electric Bay North Doors 31 Turbine Building (B-16) 267 Once/ Month once/1.5 Years Once/3 Years Elevation 272 i

Between SJAE rc Recombiner 32 Turbine Building (Y-12) 234 Once/ Month once/1.5 Years once/3 Years Elevation 272 Near Stairwell to E.H.C.

33 Turbine Building (P-13) 235 Once/ Month Once/1.5 Years Once/3 Years Elevation 272 I

Near Electric-Bay South Doors 34 Turbine Building (E-13) 220 Once/ Month Once/1.5 Years Once/3 Years Elevation 292 East of Panel HV-1 35 Turbine Building (C-12) 215 Once/ Month- Once/1.5 Years Once/3 Years Elevation 300 Entrance to Administration Bui3 ding 36 Screen House (B-24)- 209 .Once/ Month once/1.5 Years Once/3 Years Elevation 255 West - Near Traveling Screen A R=v._No. Page O of 57

TECH SPEC RELATED REQUIREMENTS, LISTS AND TABLES

  • AP-01.04 ATTACHMENT 2 Page 34 of 34 FIRE PROTECTION REOUIEEMENLS TABLE 6 MANUAL FIRE HOSE STATION TESTS STATION LOCATION HOSE VALVE / HOSE / GASKET FLOW /

NUMBER STATION NOZZLE INSPECTION / HYDROSTATIC VALVE INSPECTION HOSE RERACK TEST

  • NUMBER 37 RHR/ESW Pump Room (B-26) 208 Once/ Month once/1.5 Years Once/3 Years Elevation 255 West Side - Near Electric Fire Pump Controller 38 Screen House (Be-28) 207 Once/ Month Once/1.5 Years Once/3 Years Elevation 260 North - Near Circulating Water Discharge Gates 39 Screen House (Bh-24) 211 Once/ Month once/1.5 Years once/3 Years Elevation 260 East - Near City Water Tank 40 Screen House (Ba-26) 206 Once/ Month once/1.5 Years Once/3 Years Elevation 272 West Side Between Panels HV-11A & B NOTES FOR TABLE 6
1) Hydrostatic of the hose at a pressure at least 50 psig greater than the maximum pressure available at the hose station.

4 Rsv. No. Page M of 57

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