Text

Request for Change to Technical Specifications Regarding Mode Change Limitations Using the Consolidated Line Item Improvement Process (CLIIP) Salem Units 1 & 2
	ML061220746
Person / Time
Site:	Salem
Issue date:	04/25/2006
From:	Joyce T; Public Service Enterprise Group
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	LCR S06-04, LR-N06-0120, TSTF-359, Rev 9
	Download: ML061220746 (101)
	v • d • e

PSEG Nuclear LLC P.O. Box 236, Hancocks Bridge, New Jersey 08038-0236 5 ~

0 PSEG~

APR 5 2006 NuclearLLC LR-N06-0120 LCR S06-04 Unilted States Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 REQUEST FOR CHANGE TO TECHNICAL SPECIFICATIONS REGARDING MODE CHANGE LIMITATIONS USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS (CLIIP)

SALEM GENERATING STATION UNITS 1 AND 2 DOCKET NOS. 50-272 AND 50-311 FACILITY OPERATING LICENSE NOS. DPR-70 AND DPR-75 In accordance with the provisions of 10 CFR 50.90, PSEG Nuclear, LLC (PSEG) hereby transmits a request for amendment of the Technical Specifications (TS) and supporting Bases for the Salem Generating Station Unit 1 and Unit 2.

Pursuant to the requirements of 10 CFR 50.91 (b)(1), a copy of this request for amendment has been sent to the State of New Jersey.

The proposed amendment would modify TS requirements for mode change limitations in TS 3.0.4 and 4.0.4, using the Consolidated Line Item Improvement Process (CLIIP) described in NRC approved industry Technical Specification Task Force (TSTF) change TSTF-359, Revision 9. provides a description of the proposed change, the requested confirmation of applicability and plant-specific verifications. Attachment 2 provides the existing TS pages marked up to show the proposed changes. summarizes the regulatory commitments made in this submittal and Attachment 4 provides the existing TS Bases pages marked up to show the proposed changes.

PSIEG requests approval of the proposed license amendment by March 1, 2007 to support Salem Unit 1 outage 1 R1 8. PSEG requests implementation within 60 days of receipt of the approved amendment.

Should you have any questions regarding this request, please contact James Mallon at (610) 765-5507.

Ab 95-2168 REV. 7/99

Document Control Desk LR-N06-01 20 fP? 2 6 2006 I declare under penalty of perjury under the laws of the United States of America that I am authorized by PSEG Nuclear, LLC to make this request and that the foregoing is true and correct.

Sincerely, Thomas P. Joyce/

Site Vice President - Salem Attachments (4)

C Mr. S. Collins, Administrator - Region I U. S. Nuclear Regulatory Commission 475 Allendale Road King of Prussia, PA 19406 Mr. S. Bailey, Licensing Project Manager - Salem U. S. Nuclear Regulatory Commission Mail Stop 08B1 Washington, DC 20555 USNRC Senior Resident Inspector - Salem Unit 1 and Unit 2 (X24)

Mr. K. Tosch, Manager IV Bureau of Nuclear Engineering P. O. Box 415 Trenton, NJ 08625

A1TACHMENT 1 LCR S06-04 LRN-06-0120 SALEM GENERATING STATION - UNIT 1 AND UNIT 2 DOCKET NO. 50-272 AND 50-311 CHANGE TO TECHNICAL SPECIFICATIONS MODE CHANGE LIMITATIONS USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS DESCRIPTION AND ASSESSMENT

1. I)ESCRIPTION The proposed amendment would modify Technical Specification (TS) requirements for mode change limitations in TS 3.0.4 and TS 4.0.4. The changes are consistent with Nuclear Regulatory Commission (NRC) approved Industry Technical Specification Task Force (TSTF) change TSTF-359, Revision 9. On April 4, 2003, the NRC published the Notice of Availability for TSTF-359, Revision 8 in Federal Register Notice 68 FR 16585. That Federal Register Notice announced the availability of this TS improvement through the consolidated line item improvement process (CLIIP). The NRC subsequently made two modifications in response to comments, as well as one editorial change, which have been incorporated into TSTF-359, Rev. 9 which was approved on May 12, 2003.

The proposed changes to TS 3.0.4 would allow entry into a MODE or other specified condition that has a specific required action and completion time after performance of an assessment that focuses on managing plant risk. In addition, the TS 3.0.4 allowances can be applied to values and parameters in specifications when explicitly stated in the TS. These changes are in addition to the current mode change allowance when a required action has an indefinite completion time. The TS 3.0.4 mode change allowances are not permitted for higher risk systems and components, and appropriate restrictions are included in the proposed change.

Adoption of TSTF-359 is predicated on adoption of a TS Bases Control Program, and Westinghouse Standard Technical Specifications (STS) SR 3.0.1 and associated bases, if not already incorporated in the TS. Salem Generating Station Units 1 and 2 previously incorporated these requirements into the TS by License Amendments 256 and 237, respectively, dated April 16, 2003. A Bases Control Program is included in Section 6.0 of the Salem Technical Specifications, consistent with the program described in the STS for Wpstinghouse Plants, NUREG-1431 Vol. 1, Rev. 2. PSEG incorporated the STS language to replace Specification 4.0.1 and supporting Bases in their entirety.

ATTACHMENT 1 LCR S06-04 LR-N06-0120

2. ASSESSMENT Applicability of published Safety Evaluation PSFEG has reviewed the safety evaluation published in Federal Register Notice 68 FR 16585, dated April 4, 2003, which supports the CLIIP. This review included a review of the NRC staffs evaluation, as well as supporting information provided for TSTF-359, Revision 9. PSEG has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by NRC staff are applicable to Salem Generating Station Unit 1 and Unit 2 and justify this amendment for incorporation of the changes into the plant's technical specifications.

Optional Changes and Variations Since Salem Generating Station Unit 1 and Unit 2 have not adopted STS, there are some administrative differences from TSTF-359, Revision 9:

1. STS SR 3.0.1 is SR 4.0.1 in the Salem TS

2. STS SR 3.0.4 is SR 4.0.4 in the Salem TS

3. STS LCO 3.4.12 is 3.4.9.3 (Unit 1) and 3.4.10.3 (Unit 2)

4. STS LCO 3.4.16 is 3.4.8 (Unit 1) and 3.4.9 (Unit 2)

5. STS LCO 3.7.5 is 3.7.1.2 in the Salem TS

6. ITS LCO 3.8.1 is 3.8.1.1 in the Salem TS

7. Administrative requirements are located under TS 6.0, not 5.0.

One minor readability change to the TS has been included with insertion of the word "or" between Limiting Condition for Operation (LCO) 3.0.4.a and 3.0.4.b to highlight the mutual exclusivity of these elements. This "or" connector was contained in both the Notice of Opportunity to Comment (67 FR 50475, 8/2/02) and the NRC Notice of Availability (68 FR 16585, 4/4/03), and appears to have been inadvertently dropped.

An editorial correction to the Salem Unit 2 Bases is also being made. The Heatup portion of Bases 3/4.4.10, RCS Pressure-Temperature Limits, contains a discussion of the reactor closure head flange metal temperature which incorrectly indicates that the limiting RTNDT value for Salem Unit 2 occurs in the closure head flange of Unit 1. This "Unit 1" reference is being changed to "Unit 2".

PSE.G is not proposing any variations or deviations from the NRC staffs model safety evaluation.

See Attachments 2 and 4 for a complete listing of the technical specifications and bases, respectively, affected by this proposed change.

2

ATTACHMENT 1 LCR S06-04 LR-N06-01 20

3. REGULATORY ANALYSIS No Significant Hazards Consideration Determination PSEG has reviewed the proposed No Significant Hazards Consideration determination included in TSTF-359, Revision 9. PSEG concludes that the proposed determination is applicable to Salem Generating Station Unit 1 and Unit 2 and it is presented below to satisfy the requirements of 1 OCFR50.91 (a).

A change is proposed to LCO 3.0.4 and SR 4.0.4 to allow entry into a MODE or other specified condition in the Applicability while relying on ACTIONS after perlormance of a risk assessment. LCO 3.0.4 exceptions in individual Specifications would be eliminated. LCO 3.0.4 mode change allowances are not permitted for higher risk systems and components, and appropriate restrictions are included in the proposed change. SR 4.0.4 is revised to reflect the LCO 3.0.4 allowance. LCO 3.0.4 and SR 4.0.4 have been expanded to apply in all MODES.

In accordance with the criteria set forth in 10 CFR 50.92, PSEG has evaluated these proposed Improved Technical Specification changes and determined they do riot represent a significant hazards consideration. The following is provided in support of this conclusion.

1. Dloes the change involve a significant increase in the probability or consequences of an accident previously evaluated?

The proposed change allows entry into a MODE while relying on ACTIONS.

Being in an ACTION is not an initiator of any accident previously evaluated.

Consequently, the probability of an accident previously evaluated is not significantly increased. The consequences of an accident while relying on ACTIONS as allowed by the proposed LCO 3.0.4 are no different than the consequences of an accident while relying on ACTIONS for other reasons, such as equipment inoperability. Therefore, the consequences of an accident previously evaluated are not significantly increased by this change. Therefore, this change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the change create the possibility of a new or different kind of accident from any accident previously evaluated?

The proposed change does not involve a physical alteration of the plant (no new or different type of equipment will be installed). Thus, this change does not create the possibility of a new or different kind of accident from any accident previously evaluated; there is no change to the design basis.

3

A1TACHMENT 1 LCR S06-04 LR-N06-01 20

3. Does this change involve a significant reduction in a margin of safety?

The proposed change allows entry into a MODE or other specified conditions in the Applicability while relying on ACTIONS. The Technical Specifications allow operation of the plant without a full complement of equipment. The risk associated with this allowance is managed by the imposition of ACTIONS and Cormpletion Times. The net effect of ACTIONS and Completion Times on the margin of safety is not considered significant. The proposed change does not change the ACTIONS or Completion Times of the Technical Specifications. The proposed change allows the ACTIONS and Completion Times to be used in new circumstances. However, this use is predicated on an assessment that focuses on managing plant risk. In addition, most current allowances to utilize the ACTIONS and Completion Times that do not require risk assessment are eliminated. As a result, the net change to the margin of safety is insignificant.

Therefore, this change does not involve a significant reduction in a margin of safety.

Verication and Commitments As discussed in the Notice of Availability published in Federal Register Notice 68 FR 16585, dated April 4, 2003 for this TS improvement, the following plant-specific verifications were performed.

PSEG has established TS Bases for LCO 3.0.4 and SR 4.0.4 that state that use of the TS mode change limitation flexibility established by LCO 3.0.4 and SR 4.0.4 is not to be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to operable status before entering an associated mode or other specified condition in the TS Applicability. Also included are changes to the TS Bases for LCO 3.0.4 and SR 4.0.4 that provide details on how to implement the new requirements.

The proposed amendment includes bases changes that provide guidance for changing Modes or other specified conditions in the Applicability when an LCO is not met. The bases changes describe in detail how:

(1) L.CO 3.0.4.a allows entry into a MODE or other specified condition in the Applicability with the LCO not met when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time.

(2) LCO 3.0.4.b allows entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate. For a small subset of systems and components that have been 4

ATTACHMENT 1 LCR S06-04 LR-N06-01 20 determined to be more important to risk, an ACTION was added to the LCO governing these systems and components prohibiting use of the LCO 3.0.4.b allowance.

(3) LCO 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met based on a provision in the Specification, whi:h is typically applied to Specifications which describe values and parameters (e.g., Containment Air Temperature, Containment Pressure, Moderator Temperature Coefficient), although it may be applied to other Specifications based on NRC plant-specific approval.

The bases also state that any risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide 1.182. "Assessing and Managing Risks Before Maintenance Activities at Nuclear Power Plants," and that the results of the risk assessment shall be considered in determining the acceptability of entering the MODE or other specified condition in the Applicability, and any corresponding risk management actions. Prior to implementation of the revised TS, the PSEG plant procedures that implement 10 CFR 50.65(a)(4) will be modified to address the situation where entering a MODE or other specified condition in the Applicability is contemplated with plant equipment not OPERABLE. The procedure will state that LCC) 3.0.4.b should not be used unless there is a reasonable probability of completing restoration such that the requirements of the LCO would be met prior to expiration of the ACTION completion times that would require exiting the Applicability.

In addition, the bases state that upon entry into a MODE or other specified condition in the Applicability with the LCO not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the unit is not within the Applicability of the Technical Specification. The bases also state that SR 4.0.4 does not restrict changing MODES or other specified conditions of the Applicability when a Surveillance has not been performed within the specified Frequency, provided the requirement to declare the LCO not met has been delayed in accordance with SR 4.0.3.

4. ENVIRONMENTAL EVALUATION PSEEG has reviewed the environmental evaluation included in the model safety evaluation from 68 FR 16585, dated April 4, 2003 and has concluded that the staffs findings presented in the evaluation are applicable to Salem Generating Station Unit 1 and Unit 2. The evaluation is hereby incorporated by reference into this application.

5

ATTACHMENT 2 LR-N06-0120 LCR S06-04 TECHNICAL SPECIFICATION PAGES WITH PROPOSED CHANGES The! following Technical Specifications for Salem Generating Station Unit 1 and Unit 2, Facility Operating License Nos. DPR-70 and DPR-75, respectively, are affected by this change request:

Salem Unit I TS No.

Title Page 3.0.4 APPLICABILITY - LIMITING CONDITION FOR OPERATION 3/4 0-1 4.0.4 APPLICABILITY - SURVEILLANCE 3/4 0-2a 3.4.8 SPECIFIC ACTIVITY 3/4 4-20 3.4.9.3 OVERPRESSURE PROTECTION SYSTEMS 3/4 4-30 3.5.3 ECCS SUBSYSTEMS - Tavg<350 'F 3/4 5-6 3.7.1.2 AUXILIARY FEEDWATER SYSTEM 3/4 7-5 3.8.1.1 A.C. SOURCES - OPERATING 3/4 8-1 The following Technical Specifications have pre-existing LCO 3.0.4 exceptions; these exceptions are being removed by this proposed change TS No.

Title Page 3.3.1.1.

REACTOR TRIP SYSTEM INSTRUMENTATION 3/4 3-3, 4, 5 3.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM 3/4 3-15, 19, INSTRUMENTATION 20, 20a, 21 3.3.3.1 RADIATION MONITORING INSTRUMENTATION 3/4 3-3%5 3.3.3.2 MOVABLE INCORE DETECTORS 3/4 3-39 3.3.3.5 REMOTE SHUTDOWN INSTRUMENTATION 3/4 3-46 3.3.3.7 ACCIDENT MONITORING INSTRUMENTATION 3/4 3-53I 3.3.3.8 RADIOACTIVE LIQUID EFFLUENT MONITORING 3/4 3-58 INSTRUMENTATION 3.3.3.9 RADIOACTIVE GASEOUS EFFLUENT OXYGEN 3/4 3-64 MONITORING INSTRUMENTATION 3.3.3.14 POWER DISTRIBUTION MONITORING SYSTEM 3/4 3-71 3.4.10.1 REACTOR COOLANT SYSTEM STRUCTURAL INTEGRITY 3/4 4-32 3.7.8.1 SEALED SOURCE CONTAMINATION 3/4 7-26 3.7.11 FUEL STORAGE POOL BORON CONCENTRATION 3/4 7-30 3.7.12 FUEL ASSEMBLY STORAGE IN THE SPENT FUEL POOL 3/4 7-31 3.9.12 _ FUEL HANDLING AREA VENTILATION SYSTEM 3/4 9-12 3.11.1.4 LIQUID HOLDUP TANKS 3/4 11-7 3.11.2.5 EXPLOSIVE GAS MIXTURE 3/4 11-15

ATTACHMENT 2 LR-N06-0120 LCR S06-04 Salom Unit 2 TS No.

Title Page 3.0.4 APPLICABILITY - LIMITING CONDITION FOR OPERATION 3/4 0-1 4.0.4 APPLICABILITY - SURVEILLANCE 3/4 0-2a 3.4.9 SPECIFIC ACTIVITY 3/4 4-23 l

3.4.10.3 OVERPRESSURE PROTECTION SYSTEMS 3/4 4-31 3.5.3 ECCS SUBSYSTEMS - Tavg<350 'F 3/4 5-7 3.7.1.2 AUXILIARY FEEDWATER SYSTEM 3/4 7-5 3.8.1.1 A.C. SOURCES - OPERATING 3/4 8-1 The following TS have pre-existing LCO 3.0.4 exceptions; these exceptions are being removed by this proposed change TS No.

Title Page 3.2.4 QUADRANT POWER TILT RATIO 3/4 2-15 3.3.1.1 REACTOR TRIP SYSTEM INSTRUMENTATION 3/4 3-3, 4, 5 3.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM 3/4 3-15,19,

_ INSTRUMENTATION 20, 21,22 3.3.3.1 RADIATION MONITORING INSTRUMENTATION 3/4 3-38 3.3.3.2 MOVABLE INCORE DETECTORS 3/4 3-42 3.3.3.5 REMOTE SHUTDOWN INSTRUMENTATION 3/4 3-43 3.3.3.7 ACCIDENT MONITORING INSTRUMENTATION 3/4 3-50 3.3.3.8 RADIOACTIVE LIQUID EFFLUENT MONITORING 3/4 3-53 INSTRUMENTATION 3.3.3.9 RADIOACTIVE GASEOUS EFFLUENT OXYGEN 3/4 3-59 MONITORING INSTRUMENTATION 3.3.3.14 POWER DISTRIBUTION MONITORING SYSTEM 3/4 3-66 3.4.11.1 REACTOR COOLANT SYSTEM STRUCTURAL INTEGRITY 3/4 4-33 3.7.8.1 SEALED SOURCE CONTAMINATION 3/4 7-21 3.7.11 FUEL STORAGE POOL BORON CONCENTRATION 3/4 7-30 3.7.12 FUEL ASSEMBLY STORAGE IN THE SPENT FUEL POOL 3/4 7-31 3.9.12 _ FUEL HANDLING AREA VENTILATION SYSTEM 3/4 9-13 3.11.1.4 LIQUID HOLDUP TANKS 3/4 11-7 3.11.2.5 EXPLOSIVE GAS MIXTURE 3/4 11-15

ATTACHMENT 2 LCR S06-04 LR-N06-01 20 SALEM GENERATING STATION UNIT I AND UNIT 2 MARKED-UP TECHNICAL SPECIFICATION PAGES Insert I (Completely replaces existing LCO 3.0.4)

When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; or

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

AT1iFACHMENT 2 LCR S06-04 LR-N06-01 20 Insert 2 (Completely replaces existing SR 4.0.4)

Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 4.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

ATTACHMENT 2 LCR S06-04 LR-N06-01 20 INSERT 3 (LCO 3.4.8 (Unit 1), LCO 3.4.9 (Unit 2) - RCS SPECIFIC ACTIVITY)

c. L.CO 3.0.4.c is applicable.

INSERT 4 (LCO 3.4.9.3 (Unit 1), 3.4.10.3 (Unit 2), OVER PRESSURE PROTECTION SYSTEM)

e. L.CO 3.0.4.b is not applicable when entering MODE 4.

INSERT 5 (LCO 3.5.3, ECCS SHUTDOWN)

d. L.CO 3.0.4.b is not applicable to ECCS high head subsystem INSERT 6 (LCO 3.7.1.2, AFW SYSTEM)

d. LCO 3.0.4.b is not applicable.

INSERT 7 (LCO 3.8.1, AC SOURCES)

h. LCO 3.0.4.b is not applicable to DGs.

3/4.0 APPLICABILITY LIMITING CONDITION FOR OPERATION 3.0.1 compliance with the limiting Conditions for Operation contained in the succeed:ng specifications is required during the OPERATIONAL MODES or other conditions specified therein; except that upon failure to meet the Limiting Conditions for Operation, the associated ACTION requirements shall be met.

3.0.2 Noncompliance with a specification shall exist when the requirements of the Limiting Condition for Operation and associated ACTION requirements are not met within the specified time intervals.

If the Limiting Condition for Operation is restored prior to expiration of the specified time intervals, completion of the ACTION requirements is not required.

3.0.3 When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in:

1.

At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

2.

At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

3.

At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Where corrective measures are completed that permit operation under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits a.s measured from the time of failure to meet the Limiting Condition for Operation.

Exceptions to these requirements are stated in the individual specifications.

3.0.4 Entry into an OPERATIONAL M E or other specified conditi (E.)

shall not be made whe the conditions of the Limiti g Condition for Operation are not met an the associated ACTION requi s a shutdown if they are not met within a sp cified time interval.

(h) may be made in cordance with ACTION requir ents when conformance to them permits cont ed operation of the facili for an unlimited period o time.

This prcvision shal not prevent passage through or to OPERATIONAL MODES as required to compl with ACTION requirements.

ceptions to these requirement:s are stated i ndividual specifications.

Atl IInse.

SALEM -

UNIT I 3/4 0-1 Amendment No.

1.;1

SURVEILLANCE REQUIREMENTS 4.0.1 Surveillance Requirements shall be met during the OPERATIONAL MODES or other specified conditions in the Applicability for individual Limiting Conditions for Operation, unless otherwise stated in the Surveillance Requirement. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the Limiting Condition for Operation.

Failure to perform a Surveillance within the specified frequency shall be faf.lure to meet the Limiting Condition for Operation, except as provided in Specification 4.0.3.

Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

4.0.2 Each Surveillance Requirement shall be performed within the specified surveillance interval with a maximum allowable extension not to exceed 25 percent of the specified surveillance interval.

4.0.3 If it is discovered that a Surveillance was not performed within its specified frequency, then compliance with the requirement to declare the Limiting Conditicn for Operation not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified frequency, whichever is greater.

This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the Limiting Conditicn for Operation must immediately be declared not met and the applicable Actions must be entered.

When the Surveillance is performed within the delay period and the Surveillance is not ret, the Limiting Condition for Operation must immediately be declared not met and the applicable Actions must be entered.

4.0.4 Entry into an RATIONAL MODE or other s cified condition shall not made unless the Su illance Requirement(s) as ciated with the Limiting l

Condition for Ope tion have been performed wthin the stated surveillance interval or as o erwise specified.

This ovision shall not prevent passageJ through or to ERATIONAL MODES as requ ed to comply with ACTION reqcuireTj se 4.0.5 Surveillance Requirements for inservice inspection and testing of ASME 1

1 Code Class 1, 2 and 3 components shall be applicable as follows:

a.

Inservice inspection of ASME Code Class 1, 2 and 3 componer.ts and inservice testing of ASME Code Class 1, 2 and 3 pumps and valves shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 1C CFR 50, Section 50.55a(g), except where specific written relief has been granted by the Commission pursuant to 10 CFR 50, Section 50.55a(g) (6) (i).

b.

Surveillance intervals specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda for the inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and applicable Addenda shall be applicable as follows in these Technical Specifications:

SALEM - UNIT 1 3/4 0-2a Amendment No.256

REACTOR COOLANT SYSTEM SPECIFIC ACTIVITY LIMITING CONDITION FOR OPERATION 3.4.8 The specific activity of the primary coolant shall be limited to:

a.

1.0 pCi/gram DOSE EQUIVALENT I-131, and

b.

100/EpCi/gram.

APPLICABILITY:

MODES 1, 2, 3, 4 and 5 ACTION:

MODES 1, 2 and 3*

a.

With the specific activity of the primary coolant > 1.0 pCi/gram DOSE EQUIVALENT I-131 for more than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months during one continuous time interval or exceeding the limit line shown on Figure 3.4-1, be in at least HOT STANDBY with Tavg < 5000 F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With the specific activity of the primary coolant > 100/E pCi/gram, be in at least HOT STANDBY with Tavg < 5000 F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

MODES 1, 2, 3, 4 and 5

a.

With the specific activity of the primary coolant > 1.0 pCi/gram DOSE EQUIVALENT I-131 or > 100/E pCi/gram, perform the sampling and analysis requirements of item 4a of Table 4.4-4 until the specific activity of the primary coolant is restored to within its limits.

SURVEILLANCE REQUIREMENTS 4.4.8 The specific activity of the primary coolant shall be determined to be within the limits by performance of the sampling and analysis program of Table 4.4-4.

With Tan.g 2 5000F.

SALEM -

UNIT 1 3/4 4-20 Amendment No. 22E

REACTOR COOLANT SYSTEM OVERPRESSURE PROTECTION SYSTEMS LIMITING CONDITION FOR OPERATION 3.4.9.3 At least one of the following overpressure protection systems shall be OPERABLE:

a.

Two Pressurizer Overpressure Protection System relief valves (POPS) with a lift setting of less than or equal to 375 psig, or

b.

A reactor coolant system vent of greater than or equal to 3.14 square inches.

APPLICABIL::TY:

When the temperature of one or more of the RCS cold legs is less than or equal to 312'F, except when the reactor vessel head is removed.

ACTION:

Insert 4

a.

With one POPS inoperable in MODE 4 and the temperature of one or more of the RCS cold legs is less than or equal to 3120F, either restore the inoperable POPS to OPERABLE status within 7 days or depressurize and vent the RCS through a 3.14 square inch vent(s) within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; maintain the RCS in a vented condition until both POPSs have been restored to OPERABLE status.

b.

With one POPS inoperable in MODES 5 or 6 with the Reactor Vessel Head installed, restore the inoperable POPS to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or complete depressurization and venting of the RCS through at least a 3.14 square inch vent(s) within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; maintain the RCS in a vented condition until both POPSs have been restored to OPERABLE status.

c.

With both POPSs inoperable, depressurize and vent the RCS through a 3.14 square inch vent(s) within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; maintain the RCS in a vented condition until both POPSs have been restored to OPERABLE status.

d.

In the event either the POPS or the RCS vent(s) are used to mitigate a RCS pressure transient, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 30 days. The report shall describe the circumstances initiating the transient, the effect of the POPS or vent(s) on the transient and any

_corrective action necessary to prevent recurrence.

SALEM - UNIT 1 3/4 4-30 Amendment No. 150

EMERGENCY CORE COOLING SYSTEMS ECCS SUBSYSTEMS -

Tavq <350'F LIMITING CONDITION FOR OPERATION 3.5.3 As a minimum, one ECCS subsystem comprised of the following shall be OPERABLE:

a.

One OPERABLE centrifugal charging pump* and associated flow path capable of taking suction from the refueling water storage tank and transferring suction to the residual heat removal pump discharge piping and;

1.

Discharging into each Reactor Coolant System (RCS) cold leg.

b.

One OPERABLE residual heat removal pump and associated residual heat removal heat exchanger and flow path capable of taking suction from the refueling water storage tank on a safety injection signal and transferring suction to the containment sump during the recirculation phase of operation and;

1.

Discharging into each RCS cold leg, and; upon manual initiation,

2.

Discharging into two RCS hot legs.

APPLICABILITY: MODE 4.

ACTION:

Insert 5

a.

With no ECCS subsystem OPERABLE because of the inoperability of either the centrifugal charging pump or the flow path from the refueling water storage tank, restore at least one ECCS subsystem to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in COLD SHUTDOWN within the next 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months .

b.

With no ECCS subsystem OPERABLE because of the inoperability of either the residual heat removal heat exchanger or residual heat removal pump, restore at least one ECCS subsystem to OPERABLE status or maintain the Reactor Coolant System Tavg less than 3500 F by use of alternate heat removal methods.

c.

In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 90 days describimg the circumstances of the actuation and the total accumulated actuation cycles to date.

A maximum of one safety injection pump or one centrifugal charging pump shall be OPERABLE in MODE 4 when the temperature of one or more of the RCS cold leas is less than or equal to 312'F, Mode 5, or Mode 6 when the head is on the reactor vessel.

SALEM - UNIT 1 3/4 5-6 Amendment Nc. 225 l

PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater pumps and associated manual activation switches in the control room and flow paths shall be OPERABLE with:

a.

Two feedwater pumps, each capable of being powered from separate vital busses, and

b.

One feedwater pump capable of being powered from an OPERABLE steam supply system.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

Inet 6

a.

With one auxiliary feedwater pump inoperable, restore the required auxiliary feedwater pumps to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With two auxiliary feedwater pumps inoperable be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 63 hours7.291667e-4 days 0.0175 hours 1.041667e-4 weeks 2.39715e-5 months .

c.

With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary feedwater punp to OPERABLE status as soon as possible.

SURVEILLANCE REQUIREMENTS 4.7.1.2 Each auxiliary feedwater pump shall be demonstrated OPERABLE:

a.

At least once per 31 days by:

1.

Verifying that each non-automatic valve in the flow path that is not locked, sealed or otherwise secured in position, is in its correct position.

2.

Verify the manual maintenance valves in the flow path to each steam generator are locked open.

SALEM - UNIT 1 3/4 7-5 Amendment No.

153

3/4.8 E 4ECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES OPERATING LIMITING CONDITION FOR OPERATION 3.8.1.1 As a minimum, the following A.C. electrical power sources shall be OPERABLE:

a.

Two physically independent A.C. circuits between the offsite transmission network and the onsite Class lE distribution system (vital bus system), and

b.

Three separate and independent diesel generators with:

1.

Separate day tanks containing a minimum volume of 130 gallons of fuel, and

2.

A common fuel storage system consisting of two storage tanks, each containing a minimum volume of 23,000 gallons of fuel, and two fuel transfer pumps.

APPLICABILITY:

MODES 1, 2, 3 and 4.

ACTION:

a.

With an independent A.C. circuit of the above required A.C.

electrical power sources inoperable:

1.

Demonstrate the OPERABILITY of the remaining independent A.C.

circuit by performing Surveillance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and

2.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , declare required systems or components with no offsite power available inoperable when a redundant required system or component is inoperable, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and

3.

Restore the inoperable independent A.C. circuit to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

b.

With one diesel generator of the above required A.C. electrical power sources inoperable:

1.

Demonstrate the OPERABILITY of the independent A.C. circuits by performing Surveillance Requirement 4.8.1.1.1.a within 1 hcur and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and item

2.

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , declare required systems or components

,age supported by the inoperable diesel generator inoperable when a

-2a required redundant system or component is inoperable, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and SALEM - UNIT 1 3/4 8-1 Amendment No.253

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NUMBER OF CHANNELS FUNCTIONAL UNIT

11.

Pressurizer Water Level--High 3

3/loop CHANNELS TO TRIP 2

2/loop in any oper-ating loop MINIMUM CHANNELS OPERABLE 2

2/loop in each oper-ating loop APPLICABLE MODES 1, 2 1

ACTION 6 < 11"

12.

Loss of Flow -

Single Loop (Above P-8)

13.

Loss of Flow -

Two Loops (Above P-7 and below P-8)

14.

Steam Generator Water Level--

Low-Low 3/loop 3 /loop 2/loop in two oper-ating loops 2 /loop in any oper-ating loops 2/loop in each oper-ating loop 2/loop in each oper-ating loop 1

1, 2

15.

Deleted

16.

Undervoltage-Reactor Coolant Pumps

17.

Underfrequency-Reactor Coolant Pumps 4-1/bus 4-1/bus 1/2 twice 1/2 twice 3

3 1

1 6

6 SALEM -

UNIT 1 3/4 3-3 Amendment No.

173 Corrected by letter

,J- _.

UU n

I ^ 00 aM I-U U U.

Y

J, I

J

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NUMBER FUNCTIONAL UNIT OF CHANNELS CHANNELS TO TRIP MINIMUM CHANNELS OPERABLE APPLICABLE MODES ACTION

18.

Turbine Trip

a. Low Autostop Oil Pressure

b. Turbine Stop Valve Closure

19.

Safety Injection Input from ESF 3

4 2

2 4

1 2

3 2

1 1

1,2 10

20.

Reactor Coolant Pump Breaker Position Trip (above P-7) 1/breaker 2

1/breaker per opera-ting loop 1

11

21.

Reactor Trip Breakers

22.

Automatic Trip Logic 2

1 1

2 2

1, 2

3*, 4*, 5*

1, 2

3*, 4*, 5*

1###, 14 13 10 13 2

SALEM - UNIT 1 3/4 3-4 Amendment No. 142

TABLE 3.3-1 (Continued)

TABLE NOTATION With the reactor trip system breakers in the closed position and the control rod drive system capable of rod withdrawal.

The provisions of Specification 3.0.4 are not applicable.

High voltage to detector may be de-energized above P-6.

1. 1. If ACTION Statement 1 is entered as a result of Reactor Trip Breaker (RTB) or Reactor Trip Bypass Breakers (RTBB) maintenance testing results exceeding -:he following acceptance criteria, NRC reporting shall be made within 30 days in accordance with Specification 6.9.2:

1.

A RTB or RTBB trip failure during any surveillance test with less than or equal to 300 grams of weight added to the breaker trip bar.

2.

A RTB or RTBB time response failure that results in the overall reactor trip system time response exceeding the Technical Specification limit.

ACTION STATEMENTS ACTION 1 With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1.1 provided the other channel is OPERABLE.

ACTION 2 With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

c.

Either, THERMAL POWER is restricted to

75% of RATED THERMAL POWER and the Power Range, Neutron Flux trip setpoint is reduced to < 85% of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

SALEM UNIT 1 3/4 3-5 Amendment No. 142

ENGII FUNCTIONAL UNIT

1. SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION

a. Manual Initiation

b. Automatic Actuation Logic

c. Containment Pressure-High

d. Pressurizer Pressure-Low

e. Differential Pressure Between Steam Lines -

High

f. Steam Flow in Two Steam Lines-High TABLE 3.3-3 1EERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL W.

M.

CI-7TINELS CMuITNhLS L

pr' L:

OF CHANNELS TO TRIP OPERABLE MO]DES ACTION 2

2 3

3 3/steam line 2/steam. line 1

1 2

2 2/steam line any steam line 1/steam line any 2 steam lines 2

2 2

2 2/steam line 1/steam line 1,2,3,4 1,2,3,4 1,2,3 1,2, 3#

1,2, 3##

18 13 1

1 1

I I

I COINCIDENT WITH EITHER Tavg -- Low-Low OR, COINCIDENT WITH Steam Line Pressure-Low 1 Tavg/loop 1 pressure/

loop 1 Tavg in any 2 loops 1 pressure any 2 loops 1 Tavg in any 3 loops 1 pressure any 3 loops 1,2, 3##

1,2,3##

,G?"'

le_

I I

SALEM -

UNIT 1 3/4 3-15 Amendment No. 142

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAT. NO.

CHANNELTS rUH!NMELS Al OF CHANNELS TO TRIP OPERABLE FUNCTIONAL UNIT

4.

STEAM LINE ISOLATION MOET Tf'SnT -

MODES ACTION

a.

Manual 2/steam line 1/steam line 1/operating steam line

b.

Automatic Actuation Logic

c. Containment Pressure--High-High

d.

Steam Flow in Two Steam Lines--High 1

2 2

3 1,2,3 1,2,3 1,2,3 1, 2,3##

23 4

2/steam line 20 161ge 1/steam line any 2 steam lines 1/steam line I

COINCIDENT WITH EITHER Tavg--Low-Low 1 C

1 Tavg/loop 1 Tavg in any 2 loops 1 Tavg in any 3 loops 1,2, 3##

I OR, COINCIDENT WITH 1al Steam Line Pressure-Low 1 pressure/

loop 1 pressure any 2 loops 1 pressure any 3 loops 1,2, 3##

I SqALEM -

UIT T 1 A

- N I 1 m

m I/

-. ~

Amendment imo. i4 2

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TUTAb NO.

CHANNELS CHANNELS APPLI OF CHANNELS TO TRIP OPERABLE MOE FUNCTIONAL UNIT

[CABLE

)ES ACTION

5. TURBINE TRIP & FEEDWATER ISOLATION

a. Steam Generator Water level--

High-High 3/loop 2/loop in any operating loop 2/loop in each operating loop 1,2,3 I

I

6.

SAFEGUARDS EQUIPMENT CONTROL SYSTEM (SEC)

7.

UNDERVOLTAGE, VITAL BUS

a.

Loss of Voltage

b.

Sustained Degraded Voltage 3

1/bus 3/bus 2

2 2/bus 3

3 3/bus 1,2,3,4 1,2,3 1,2,3 13 1*,:"

, r II SALEM - UNIT 1 3/4 3-20 Amendment No. 142

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO CHANNELS CHANNELS APPLICABLE OF CHANNELS TO TRIP OPERABLE MODES kUNCTIONAL UNIT

8.

AUXILIARY FEEDWATER ACTION

a.

Automatic Actuation Logic **

2

b.

NOT USED

c.

Steam Generator Water Level--Low-Low

i. Start Motor Driven Pumps 3/stm. gen.

1 2

1,2,3 20 l&3 9d ii.Start Turbine Driven Pumps

d.

Undervoltage -

RCP Start Turbine -

Driven Pump

e.

S.I. Start Motor-Driven Pumps

f.

Trip of Main Feedwater Pumps Start Motor Driven Pumps

g.

Station Blackout 3/stm. gen.

4-1/bus 2/stm. gen.

any stm.gen.

2/stm. gen.

any 2 stm.gen.

1/2 x 2 2/stm.gen.

2/stm.gen.

3 1,2,3 1,2,3 1,2 I

19 See 1 above (All S.I. initiating functions and 2/pump 1/pump 1/pump 1,2 requirements) 2 0ff I

I See 6 and 7 above (SEC and U/V Vital Bus)

SALEM - UNIT 1 3/4 3-20a Amendment No. 175

TABLE 3.3-3 (Continued)

TABLE NOTATION Trip function may be bypassed in this MODE below P-11.

Trip function may be bypassed in this MODE below P-12.

A;;

Thc A*;,;on of-Pp.4

9ci ficati n 3.0.

-4 arc-no AI=nnI4P;;icabP.

-eS I

Applies to Functional Unit 8 items c and d.

The automatic actuation logic includes two redundant solenoid operated vent valves for each Main Steam Isolation Valve.

One vent valve on any one Main Steam Isolation Valve may be isolated without affecting the function of the automatic actuation logic provided the remaining seven solenoid vent valves remain OPERABLE. The isolated MSIV vent valve shall be returned to OPERAELE status upon the first entry into MODE 5 following determination that the vent valve is inoperable.

For any condition where more than one of the eight solenoid vent valves are inoperable, entry into ACTION 20 is required.

ACTION 13 -

ACTION 14 -

ACTION 15 -

ACTION 16 -

ACTION STATEMENTS With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or, be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1 provided the other channel is OPERABLE.

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed until performance of the next required CHANNEL FUNCTIONAL TEST, provided the inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

NOT USED With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is demonstrated by CHANNEL CHECK within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; one additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1.

With less than the Minimum Channels OPERABLE, operations may cont:.nue provided the containment purge and exhaust valves are maintained closed.

With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

ACTION 17 -

ACTION 18 -

SALEM - UNI[T 1 3/4 3-21 Amendment No. 142

INSTRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RADIATION MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.1 The radiation monitoring instrumentation channels shown in Table 3.3-6 shall be OPERABLE with their alarm/trip setpoints within the specified limits.

APPLICABILITY: As shown in Table 3.3-6.

ACTION:

a.

With a radiation monitoring channel alarm/trip setpoint exceeding the value shown in Table 3.3-6, adjust the setpoint to within the limit within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels inoperable, take the ACTION shown in Table 3.3-6.

c.

The provisions of Specification@ 3.0.3 an6d ;.0.

are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.1 Each radiation monitoring instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, SO)URCE CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the modes and at the frequencies shown in Table 4.3-3.

SALEM -

UNIT 1 3/4 3-35 Amendment No. 225

INSTRUMENTATION MOVABLE INCORE DETECTORS LIMITING CONDITION FOR OPERATION 3.3.3.2 The movable incore detection system shall be OPERABLE with:

a.

At least 75% of the detector thimbles,

b.

A minimum of 2 detector thimbles per core quadrant, and

c.

Sufficient movable detectors, drive, and readout equipment to map these thimbles.

APPLICABILITY: When the movable incore detection system is used for:

a.

Recalibration of the excore neutron flux detection system,

b.

Monitoring the QUADRANT POWER TILT RATIO, or

c.

Measurement of F.Hand FQ(Z)

ACTION:

With the movable incore detection system inoperable, do not use the system for the above applicable monitoring or calibration functions. The provisions of Specificatione 3.0.3 and -. 0.4 are not applicable.

SURVEILIANCE REQUIREMENTS 4.3.3.2 The movable incore detection system shall be demonstrated OPERABLE by normalizing each detector output to be used during its use when required for:

a.

Recalibration of the excore neutron flux detection system, or

b.

Monitoring the QUADRANT POWER TILT RATIO, or

c.

Measurement of F, and FQ(Z)

SALEM -

UNIT 1 3/4 3-39

INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.5 The remote shutdown monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE with readouts displayed external to the control room.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a.

With the number of OPERABLE remote shutdown monitoring channels less than required by Table 3.3-9, either restore the inoperable channel to OPERABLE status within 30 days or be in HOT SHUTDOWN within the nex-12 hours.

Li T'he Jo icion or!

"ptcI

-eetton

.u.

ar not aPr.lca-lc.

SURVEILLANCE REQUIREMENTS 4.3.3.5 Each remote shutdown monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-6.

SALEM -

UNIT 1 3/4 3-4 6

INSTRUMENTATION ACCIDEN¶' MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.7 The accident monitoring instrumentation channels shown in Table 3.:3-11 shall be operable.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a.

As shown in Table 3.3-11.

L5.

Thz_ __-

qf spZeiLLZtion ii.o.

__g No_

t rieabie.

SURVEILLANCE REQUIREMENTS

======:====================================================================:

4.3.3.7 Each accident monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK AND CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-11.

SALEM - 'UNIT 1 3/4 3-53 Amendment No. 225 l

INSTRUMENTATION RADIOACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.8 The radioactive liquid effluent monitoring instrumentation channels shown in Table 3.3-12 shall be OPERABLE to ensure that the limits of ODCM Control 3.11.1.1 are not exceeded.

APPLICABILITY: At all times.

ACTION:

a.

Not Used

b.

With less than the minimum number of radioactive liquid effluent monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 3.3-12.

Exert best efforts to return the instrument to OPERABLE status within 30 days and, if unsuccessful, explain in the next annual radioactive effluent release report why the inoperability was not corrected in a timely manner.

c.

The provisions of Specifications 3.0.3 and 8.014 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.8 Each radioactive liquid effluent monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL CALIBRATION, and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-12.

SALEM - UJNIT I 3/4 3-58 Amendment No 234.

INSTRUMENTATION RADIOACTIVE GASEOUS EFFLUENT OXYGEN MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.9 The radioactive gaseous effluent oxygen monitoring instrumentation channels shown in Table 3.3-13 shall be OPERABLE with their alarm/trip setpoints set to ensure that the limits of Specification 3.11.2.5 are not exceeded.

APPLICABILITY: As shown in Table 3.3-13 ACTION:

a.

With a radioactive gaseous effluent oxygen monitoring instrumentation channel alarm/trip setpoint less conservative than required by the above specification, declare the channel inoperable and take the ACTION shown in Table 3.3-13.

b.

With less than the minimum number of radioactive gaseous effluent oxygen monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 3.3-13.

Exert best efforts to return the instrument to OPERABLE status within 30 days and, if unsuccessful.,

prepare and submit a Special Report pursuant to Specification 6.9.2 to explain why the inoperability was not corrected in a timely manner.

c.

The provisions of Specifications 3.0.3 and

.Gi4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.9 Each radioactive gaseous effluent oxygen monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL CALIBRATION, and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-13.

SALEM - UNIT I 3/4 3-64 Amendment No. 234

INSTRUMENTATION POWER DISTRIBUTION MONITORING SYSTEM LIMITING CONDITION FOR OPERATION (Continued)

APPLICA13ILTY: MODE 1, above 25% RATED THERMAL POWER (RTP)

ACTION:

With any of the operability criteria listed in 3.3.3.14.a, 3.3.3.14.b, or 3.3.3.14.c not met, either correct the deficient operability condition, or declare the PDMS inoperable and use the incore movable detector system, satisfying the OPERABILITY requirements listed in Specification 3.3.3.2, to obtain any required core power distribution measurements.

Increase the measured core peaking factors using the values listed in the COLR for the PDMS inoperable condition.

The provisions of Specificatione 3.0.3 a-d -Q.04 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.14.1 The operability criteria listed in 3.3.3.14.a, 3.3.3.14.b, and 3.3.3.14.c shall be verified to be satisfied prior to acceptance of the PDMS core power distribution measurement results.

4.3.3.14.2 Calibration of the PDMS is required:

a. At least once every 180 Effective Full Power Days when the minimum number and core coverage criteria as defined in 3.3.3.14.b.1 and 3.3.3.14.b.2 are satisfied, or

b. At least once every 31 Effective Full Power Days when only the minimum number criterion as defined in 3.3.3.14.b.3 is satisfied.

SALEM -

UNIT I 3 / 4 3-71 Amendment No.

237

REACTOR COOLANT SYSTEM 3.4.10 STRUCTURAL INTEGRITY ASME CODE CLASS 1, 2 and 3 COMPONENTS LIMITING CONDITION FOR OPERATION

=====:=====================================================================:

3.4.10..

The structural integrity of ASME Code Class 1, 2 and 3 component shall be maintained in accordance with Specification 4.4.10.1.1.

APPLICABILITY: ALL MODES ACTION:

a.

With the structural integrity of any ASME Code Class 1 component(s) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) prior to increasing the Reactor Coolant:

System temperature more than 500 F above the minimum temperature required by NDT considerations.

b.

With the structural integrity of any ASME Code Class 2 component's) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) prior to increasing the Reactor Coolant:

System temperature above 200'F.

c.

With the structural integrity of any ASME not conforming to the above requirements, integrity of the affected component(s) to the affected component(s) from service.

Code Class 3 component:s) restore the structural within its limit or isolate

.4 1

I et.

lnC-t V+/-;5V1315+/-t 01 bPeejl+/-dl0dtdlOf :. U..4 arc not api caz I

SURVEILLANCE REQUIREMENTS

============================================================================:

4.4.10.1.1 The structural integrity of ASME Code Class 1, 2 and 3 components shall be demonstrated:

a.

Per the requirements of Specification 4.0.5, and

b.

Per the requirements of the augmented inservice inspection program specified in Specification 4.4.10.1.2.

SALEM - UNIT 1 3/4 4-32 Amendment No. 225

PLANT SYSTEMS 3/4.7.8 SEALED SOURCE CONTAMINATION LIMITING CONDITION FOR OPERATION 3.7.8.1 Each sealed source containing radioactive material either in excess of 100 microcuries of beta and/or gamma emitting material or 5 microcuries of alpha emitting material shall be free of 2 0.005 microcuries of removable contamination.

APPLICABILITY: At all times.

ACTION:

a.

Each sealed source with removable contamination in excess of the above limits shall be immediately withdrawn from use and:

1.

Either decontaminated and repaired, or

2.

Disposed of in accordance with Commission Regulations.

b.

The provisions of Specification 3.0.3 and 8.4. are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.8.1.1 Test Requirements -

Each sealed source shall be tested for leakage and/or contamination by:

a.

The licensee, or

b.

Other persons specifically authorized by the Commission or an Agreement State.

The test method shall have a detection sensitivity of at least 0.005 microcuries per test sample.

4.7.8.1.2 Test Frequencies -

Each category of sealed sources shall be tested at the frequency described below.

a.

Sources in use (excluding startup sources and fission detectors previously subjected to core flux) - At least once per six months for all seal sources containing radioactive materials.

SALEM -

UNIT 1 3/4 7-2 6

PLANT SYSTEMS 3/4.7.1 FUEL STORAGE POOL BORON CONCENTRATION LIMITING CONDITION FOR OPERATION 3.7.11 The fuel storage pool boron concentration shall be 2 800 ppm.

APPLICAI3ILITY:

When fuel assemblies are stored in the fuel storage pool and a fuel storage pool verification has not been performed since the last movement: of fuel assemblies in the fuel storage pool.

ACTION:

With fuel storage pool boron concentration not within limit:

a. Immediately suspend movement of fuel assemblies in the fuel storage pool and

b. Initiate action to:

1. immediately restore fuel storage pool boron concentration to within limit or

2. immediately perform a fuel storage pool verification.

c.

The provisions of ioG Specification 3.0.3 an-d i^.O4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.11 Verify the fuel storage pool boron concentration is within limit every 7 days.

Salem Unit 1 3/4 7-35 Amendment No.262

PLANT SYSTEMS 3/4.7.1:2 FUEL ASSEMBLY STORAGE IN THE SPENT FUEL POOL LIMITING CONDITION FOR OPERATION 3.7.12 The combination of initial enrichment, burnup, and Integral Fuel Burnable Absorber (IFBA) of each fuel assembly stored in Region 1 or Region :2, shall be within the acceptable limits described in the surveillance requirements below.

APPLICABILITY:

When any fuel assembly is stored in Region 1 or Region 2 oE the spent fuel storage pool.

ACTION:

If the requirements of the LCO are not met:

a. Immediately verify the fuel storage boron concentration meets the requirements of TS 3.7.11 and

b. Immediately initiate action to move the non-complying fuel assembly to a location that complies with the surveillance requirements.

c. The provisions of Specificatione 3.0.3 eand -.. 4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.12.1 Prior to storing fuel assemblies in Region 1, verify by administrative means that the fuel assemblies meet one of the following storage constraints:

a. Unirradiated fuel assemblies with a maximum enrichment of 4.25 wt%

U-235 have unrestricted storage.

b. Unirradiated fuel assemblies with enrichments greater than 4.25 wt% U-235 and less than or equal to 5.0 wt% U-235, that do not contain IFBA pins, may only be stored in the peripheral cells facing the concrete wall.

c. Unirradiated fuel assemblies with enrichments (E) greater than 4.25 wt% U-235 and less than or equal to 5.0 wt% U-235, which contain a minimum number cf IFBA pins have unrestricted storage.

This minimum number of IFBA pins shall have an equivalent reactivity hold-down which is greater than or equal tc the reactivity hold-down associated with N IFBA pins, at a nominal 2.35 mg B-10/linear inch loading (1.5x), determined by the equation below:

N = 42.67 (E -

4.25)

FUEL HANDLING AREA VENTILATION SYSTEM LIMITING CONDITION FOR OPERATION 3.9.12 The Fuel Handling Area Ventilation System shall be OPERABLE with:

a. Two exhaust fans and one supply fan OPERABLE and operating, and

b. Capable of maintaining slightly negative pressure in the Fuel Handling Building.

APPLICAEILITY:

During movement of irradiated fuel within the Fuel Handling Buildinc ACTION:

a. With no Fuel Handling Area Ventilation System OPERABLE, suspend all operations involving movement of fuel within the storage pool until the Fuel Handling Area Ventilation System is restored to OPERABLE status.

b. The provisions of Specificatione 3.0.3 and 8.0.1 are not applicable.

SURVEILlANCE REQUIREMENTS 4.9.12 The above required ventilation system shall be demonstrated OPERABLE:

a. At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that, the Fuel Handling Building is maintained at a slightly negative pressure with respect to atmospheric pressure.

b. At least once per 31 days by verifying both exhaust fans and one supply fan start and operate for at least 15 minutes, if not operating already.

c. At least once per 18 months by verifying a system flowrate of 19,490 cfm +/- 10% during system operation.

SALEM -

UNIT 1 3/4 9-12 Amendment No.263

RADIOACTIVE EFFLUENTS LIQUID HOLDUP TANKS*

LIMITING CONDITION FOR OPERATION 3.11.1.4 The quantity of radioactive material contained in each outdoor temporary tank shall be limited to less than or equal to 10 curies, excluding tritium and dissolved or entrained noble gases.

APPLICABILITY: At all times.

ACTION:

a.

With the quantity of radioactive material in any of the above listed tanks exceeding the above limit, immediately suspend all additions of radioactive material to the tank and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , reduce the tank contents to within the limit.

b.

The provisions of Specification 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.11.1.4 The quantity of radioactive material contained in each outdoor temporary tank shall be determined to be within the above limit by analyzing a representative sample of the tank's contents at least once per 7 days when radioactive materials are being added to the tank.

Tanks included in this Specification are those outdoor temporary tanks that are not surrounded by liners, dikes, or walls capable of holding the tank contents and that do not have tank overflows and surrounding area drains connected to the liquid radwaste treatment system.

SALEM - UNIT 1 3/4 11-7 Amendment No. 59

RADIOAC-IVE EFFLUENTS EXPLOSIVE GAS MIXTURE LIMITING CONDITION FOR OPERATION 3.11.2.5 The concentration of oxygen in the waste gas holdup system shall be limited to less than or equal to 2% by volume.

APPLICABILITY: At all times.

ACTION:

a. With the concentration of oxygen in the waste gas holdup system greater than 2% by volume but less than or equal to 4% by volume, reduce the oxygen concentration to the above limits within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

b. With the concentration of oxygen in the waste gas holdup system greater than 4% by volume immediately suspend all additions of waste gases to the system and reduce the concentration of oxygen to less than or equal to 2% by volume without delay.

c. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable..

SURVEILIANCE REQUIREMENTS 4.11.2.5 The concentrations of hydrogen and oxygen in the waste gas holdup system shall be determined to be within the above limits by continuously monitoring the waste gases in the waste gas holdup system with the oxygen monitor required OPERABLE by Table 3.3-13. If hydrogen is not measured, the concentration of hydrogen shall be assumed to exceed 4% by volume.

SALEM - UNIT 1 3/4 11-15 Amendment No.

261464 l

3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS 3/4.0 APPLICABILITY LIMITING CONDITION FOR OPERATION 3.0.1 Compliance with the limiting Conditions for Operation contained in the succeeding specifications is required during the OPERATIONAL MODES or other conditions specified therein; except that upon failure to meet the Limiting Conditions for Operation, the associated ACTION requirements shall be met.

3.0.2 Noncompliance with a specification shall exist when the requirements of the Limiting Condition for Operation and associated ACTION requirements are not met within the specified time intervals.

If the Limiting Condition for Operation is restored prior to expiration of the specified time intervals, completion of the ACTION requirements is not required.

3.0.3 When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in:

1.

At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

2.

At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

3.

At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Where corrective measures are completed that permit operation under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits as measured from the time of failure to meet the Limiting Condition for Operation.

Exceptions to these requirements are stated in the individual specifications.

3.0.4 /jntry into an OPERATIONA MODE or other specified con ion (a) shall not be mad when the conditions of the imiting Condition fo Operation are t met and the associated AC ION requires a shutc.owl if they are n met within a specified ti e interval.

(b) may be made/in accordance with ACTION equirements when conformance to them p mits continued operation o the facility for an unlimited period f time.

This provision all not prevent passage thro gh or to OPERATIONAL MODES as required to c ply with ACTION requirements.

Exceptions to these requirements are stated i the individual specification Insert 1 SALEM -

UNIT 2 3/4 0-1 Amendment No.

20E

APPLICABILITY SURVEILLANCE REQUIREMENTS 4.0.1 surveillance Requirements shall be met during the OPERATIONAL MODES or other specified conditions in the Applicability for individual Limiting Conditions for Operation, unless otherwise stated in the Surveillance Requirement. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the Limiting Condition for Operation.

Failure to perform a Surveillance within the specified frequency shall be failure to meet the Limiting Condition for Operation, except as provided in Specification 4.0.3.

Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

4.0.2 Each Surveillance Requirement shall be performed within the specified surveillance interval with a maximum allowable extension not to exceed 25 pe:rcent of the specified surveillance interval.

4.0.3 If it is discovered that a Surveillance was not performed within its specified frequency, then compliance with the requirement to declare the Lim:-ting Condition for Operation not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified frequency, whichever is greater..

This delay period is permitted to allow performance of the Surveillance. A ri.sk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the Limiting Condition for Operation must immediately be declared not met and the applicable Actions must be entered.

When the Surveillance is performed within the delay period and the Surveillance is not met, the Limiting Condition for Operation must immediately be declared not met and the applicable Actions must be entered.

4.0.4 Entry into an 0 TIONAL MODE or other spec ied condition shall not made unless the urveillance Requirement(s) a ociated with the Limiting Conditicn for Op ation have been performed wi in the stated surveillance interval or as otherwise specified.

This pr ision shall not prevent passage through or OPERATIONAL MODES as require to comply with ACTION requirement Insert 2 d.U.-r JSurveillance Requirements for inservice inspection and testing of ASME Code Class 1, 2 and 3 components shall be applicable as follows:

a.

Inservice inspection of ASME Code Class 1, 2 and 3 components and inservice testing of ASME Code Class 1, 2 and 3 pumps and valves shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50, Section 50.55a(g), except where specific written relief has been granted by the Commission pursuant to 10 CFR 50, Section 50.55a(g) (6) (i).

b.

Surveillance intervals specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda for the inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and applicable Addenda shall be applicable as follows in these Technical Specifications:

SALEM -

'JNIT 2 3/4 0-2a Amendment No.237

3/4.4.9 SPECIFIC ACTIVITY LIMITING CONDITION FOR OPERATION 3.4.9 The specific activity of the primary coolant shall be limited to:

a.

1.0 pCi/gram DOSE EQUIVALENT I-131, and

b.

100/E pCi/gram.

APPLICABILITY:

MODES 1, 2, 3, 4 and 5.

ACTION:

Insert 3 MODES 1, 2 and 3*

a.

With the specific activity of the primary coolant > 1.0 pCi/gram DOSE EQUIVALENT I-131 for more than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months during one continuous time interval or exceeding the limit line shown on Figure 3.4-1, be in at least HOT STANDBY with Tavg < 5000 F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With the specific activity of the primary coolant > 100/E pCi/gram, be in at least HOT STANDBY with Tavg < 500'F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

MODES 1, 2, 3, 4 and 5

a.

With the specific activity of the primary coolant > 1.0 pCi/gram DOSE EQUIVALENT I-131 or > 100/E pCi/gram, perform the sampling and analysis requirements of item 4a of Table 4.4-4 until the specific activity of the primary coolant is restored to within its limits.

SURVEILLANCE REQUIREMENTS 4.4.9 The specific activity of the primary coolant shall be determined to be within the limits by performance of the sampling and analysis prog::am of Table 4.4-4.

With Tag > 5000F.

SALEM -

UNIT 2 3/4 4-23 Amendment No. 206

REACTOR COOLANT SYSTEM OVERPRESSURE PROTECTION SYSTEMS LIMITING CONDITION FOR OPERATION, 3.4.10.3 At least one of the following overpressure protection systems shall be OPERABLE:

a. Two Pressurizer Overpressure Protection System relief valves (POPS) with a lift setting of less than or equal to 375 psig, or

b.

The Reactor Coolant System (RCS) depressurized with an RCS vent of greater than or equal to 3.14 square inches.

APPLICABILITY:

When the temperature of one or more of the RCS cold legs is Less than or equal to 312'F, except when the reactor vessel head is removed.

ACTION:

a.

With one POPS inoperable in MODE 4 and the temperature of one or more of the RCS cold legs is less than or equal to 3120F, restore the inoperable POPS to OPERABLE status within 7 days or depressurize and vent the RCS through a 3.14 square inch vent(s) within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; maintain the RCS in a vented condition until both POPSs have been restored to OPERABLE status.

b.

With one POPS inoperable in MODES 5 or 6 with the Reactor Vessel Head installed, restore the inoperable POPS to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or complete depressurization and venting of the RCS through at least a 3.14 square inch vent(s) within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; maintain the RCS in a vented condition until both POPSs have been restored to OPERABLE status.

c.

With both POPSs inoperable, depressurize and vent the RCS through a 3.14 square inch vent(s) within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; maintain the RCS in a vented condition until both POPSs have been restored to OPERABLE status.

d.

In the event either the POPS or the RCS vent(s) are used to mitigate a RCS pressure transient, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 30 days.

The report shall describe the circumstances initiating the transient, the effect of the POPS or vent(s) on the transient and any corrective action necessary to prevent recurrence.

SURVEILLANCE REQUIREMENTS 4.4.10.3.1 Each POPS shall be demonstrated OPERABLE by:

SALEM -

UNIT 2 3/4 4-31 Amendment No. 130

ECCS SUBSYSTEMS -

Tavg <350'F LIMITING CONDITION FOR OPERATION 3.5.3 As a minimum, one ECCS subsystem comprised of the following shall be OPERABLE:

a. One OPERABLE centrifugal charging pump and associated flow path capable of taking suction from the refueling water storage tank and transferring suction to the residual heat removal pump discharge piping and;

1. Discharging into each Reactor Coolant System (RCS) cold leg.

D. One OPERABLE residual heat removal pump and associated residual heat removal heat exchanger and flow path capable of taking suction frcm the refueling water storage tank on a safety injection signal and transferring suction to the containment sump during the recirculation phase of operation and;

1. Discharging into each RCS cold leg, and; upon manual initiation,

2. Discharging into two RCS hot legs.

APPLICAEILITY: MODE 4.

ACTION:

Insert 5

a. With no ECCS subsystem OPERABLE because of the inoperability of either the centrifugal charging pump or the flow path from the refueling water storage tank, restore at least one ECCS subsystem to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in COLD SHUTDOWN within the next 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months .

b. With no ECCS subsystem OPERABLE because of the inoperability of either the residual heat removal heat exchanger or residual heat removal pump, restore at least one ECCS subsystem to OPERABLE status or maintain the Reactor Coolant System Tavg lessthan 350'F by use of alternate heat removal methods.

c. In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 90 days describing the circumstances of the actuation and the total accumulated actuation cycles to date. The current value of the usage factor for each affected safety injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.

A maximum of one safety injection pump or one centrifugal charging pump shall be OPERABLE in MODE 4 when the temperature of one or more of the RCS cold lecs is less than or equal to 312'F, Mode 5, or Mode 6 when the head is on the reactor vessel.

SALEM - UNIT 2 3/4 5-7 Amendment No. 20E

PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater pumps and associated manual activation switches in the control room and flow paths shall be OPERABLE with:

a..

Two feedwater pumps, each capable of being powered from separate vital busses, and b..

One feedwater pump capable of being powered from an OPERABLE steam supply system.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

Insert 6

a.

With one auxiliary feedwater pump inoperable, restore the required auxiliary feedwater pumps to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With two auxiliary feedwater pumps inoperable be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c.

With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary feedwater pump to OPERABLE status as soon as possible.

SURVEILlANCE REQUIREMENTS 4.7.1.2 Each auxiliary feedwater pump shall be demonstrated OPERABLE:

a.

At least once per 31 days by:

1.

Verifying that each non-automatic valve in the flow path that is not locked, sealed or otherwise secured in position, is in its correct position.

2.

Verify the manual maintenance valves in the flow path to each steam generator are locked open.

SALEM -

UNIT 2 3/4 7-5 Amendment No. 134

3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES OPERATING LIMITING CONDITION FOR OPERATION 3.8.1.1 As a minimum, the following A.C. electrical power sources shall be OPERABLE.:

a.

Two physically independent A.C. circuits between the offsite transmission network and the onsite Class lE distribution system (vital bus system), and b..

Three separate and independent diesel generators with:

1. Separate day tanks containing a minimum volume of 130 gallons of fuel, and

2. A common fuel storage system consisting of two storage tanks, each containing a minimum volume of 23,000 gallons of fuel, and two fuel transfer pumps.

APPLICABILITY:

MODES 1, 2, 3 and 4.

ACTION:

a.

With an independent A.C. circuit of the above required A.C. electrical power sources inoperable:

1.

Demonstrate the OPERABILITY of the remaining independent A.C.

circuit by performing Surveillance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and

2.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , declare required systems or components with no offsite power available inoperable when a redundant required system or component is inoperable, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and

3.

Restore the inoperable independent A.C. circuit to OPERABLE:

status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

b.

With one diesel generator of the above required A.C. electrical power sources inoperable:

1.

Demonstrate the OPERABILITY of the independent A.C. circuits by performing Surveillance Requirement 4.8.1.1.1.a within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and 1

2.

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , declare required systems or components

t item supported by the inoperable diesel generator inoperable when a page required redundant system or component is inoperable, or be in 8-2a at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD

_I SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and SALEM - UNIT 2 3/4 8-1 Amendment No. 234

POWER D::STRIBUTION LIMITS LIMITING CONDITION FOR OPERATION (Continued)

1. Calculate the QUADRANT POWER TILT RATIO at least once per hour until:

(a) Either the QUADRANT POWER TILT RATIO is reduced to within its limit, or (b) THERMAL POWER is reduced to less than 50% of RATED THERMAL POWER.

2.

Reduce THERMAL POWER to less than 50% of RATED THERMAL POWER within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and reduce the Power Range Neutron Flux-High Trip Setpoints to less than or equal to 55% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

3.

Identify and correct the cause of the out of limit condition prior to increasing THERMAL POWER; subsequent POWER OPERATION above 50% of RATED THERMAL POWER may proceed provided that the QUADRANT POWER TILT RATIO is verified within its lim:.t at least once per hour for 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or until verified at 95% or greater RATED THERMAL POWER.

d.

The vis

f lcofatiz 3.0.1 al-c not applizaibl.

SURVEILLANCE REQUIREMENTS 4.2.4.1 The QUADRANT POWER TILT RATIO shall be determined to be within the limit above 50% of RATED THERMAL POWER by:

a.

Calculating the ratio at least once per 7 days when the alarm is OPERABLE.

b.

Calculating the ratio at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months during steady-state operation when the alarm is inoperable.

4.2.4.2 The QUADRANT POWER TILT RATIO shall be determined to be within the limit when above 75% of RATED THERMAL POWER with one Power Range Channel inoperable by obtaining a core power distribution measurement* to confirm that the normalized symmetric power distribution is consistent with the indicated QUADRANT POWER TILT RATIO at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Using either the movable incore detectors in the four pairs of symmetric thimble locations or the power distribution monitoring system.

SALEM - UNIT 2 3/4 2-15 Amendment No. 218

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NUMBER OF CHANNELS FUNCTIONAL UNIT

11.

Pressurizer Water Level--High

12.

Loss of Flow -

Single Loop (Above P-8) 3 3 /loop CHANNELS TO TRIP 2

2 /loop in any oper-ating loop MINIMUM CHANNELS OPERABLE 2

2/loop in each oper-ating loop APPLICABLE MODES 1, 2 1

ACTION

13.

Loss of Flow -

Two Loops (Above P-7 and below P-8)

14.

Steam Generator Water Level--

Low-Low 3/loop 3 /loop 2/loop in two oper-ating loops 2/loop in any oper-ating loops 2/loop in each oper-ating loop 2/loop in each oper-ating loop 1

1, 2

15.

Deleted

16.

Undevoltage-Reactor Coolant Pumps

17.

Underfrequency-Reactor Coolant Pumps 4-1/bus 4-1/bus 1/2 twice 1/2 twice 3

1 6

3 1

6 SALEM - UNIT 2 3/4 3-3 Amendment No. 154

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NUMBER FUNCTIONAL UNIT OF CHANNELS MINIMUM CHANNELS CHANNELS TO TRIP OPERABLE APPLICABLE MODES ACTION

18. Turbine Trip

a. Low Autostop Oil Pressure

b. Turbine Stop Valve Closure

19. Safety Injection Input from ESF 3

4 2

4 1

2 3

2 1

1 4

2 1,2 10

20. Reactor Coolant Pump Breaker Position Trip (above P-7)

21. Reactor Trip Breakers 1/breaker 2

1/breaker per opera-ting loop 1

11 2

2 1,2 3*, 4*, 5*

1,2 3*, 4*, 5*

1###,

13 14

22. Automatic Trip Logic 2

1 2

10 13 SALEM - UNIT 2 3/4 3-4 Amendment No. 121

TABLE 3.3-1 (Continued)

TABLE NOTATION With the reactor trip system breakers in the closed position and the control rod drive system capable of rod withdrawal.

!F~

revotns of£:09oto at-: not :pplizabli.

High voltage to detector may be de-energized above P-6.

If ACTION Statement 1 is entered as a result of Reactor Trip Breaker (RTII) or Reactor Trip Bypass Breaker (RTBB) maintenance testing results exceeding the following acceptance criteria, NRC reporting shall be made within 30 days: in accordance with Specification 6.9.2:

1.

A RTB or RTBB trip failure during any surveillance test with less than or equal to 300 grams of weight added to the breaker trip bar.

2.

A RTB or RTBB time response failure that results in the overall reactor trip system time response exceeding the Technical Specification linit.

ACTION STATEMENTS ACTION 1 With the number of channels OPERABLE one less than required ky the Minimum Channels OPERABLE requirement, be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1.1 provided the other channel is OPERABLE.

ACTION 2 With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

c.

Either, THERMAL POWER is restricted to

75% of RATED THERMAL POWER and the Power Range, Neutron Flux trip setpoint is reduced to S 85%

of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

d.

The QUADRANT POWER TILT RATIO, as indicated by the remaining three detectors, is verified consistent with the normalized symmetric power distribution obtained by using either the movable in-core detectors in the four pairs of symmetric thimble locations or the power distribution monitoring system at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months when THERMAL POWER is greater than 75% of RATED THERMAL POWER.

SALEM - UNIT 2 3/4 3-5 Amendment No. 218

TABLE 3.3-3 SAFETY FEATURE ACTUATION ENGINEERED SYST EM INSTRUMENTATION MINIMUM CHANNELS APPI OPERABLE MC FUNCTIONAL UNIT

1.

SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION

a.

Manual Initiation

b.

Automatic Actuation Logic

c.

Containment Pressure-High

d.

Pressurizer Pressure-Low

e.

Differential Pressure Between Steam Lines -

High

f.

Steam Flow in Two Steam Lines-High TOTAL NO.

OF CHANNELS 2

2 3

3 3/steam line 2/steam line CHANNELS TO TRIP 1

1 2

2 2/steam line any steam lines 1/steam line any 2 steam lines LICABLE IDES ACTION 2

2 2

2 2/steam line 1/steam line 1,2,3,4 1,2,3,4 1,2,3 1,2, 3#

1,2, 3##

18 13 1&_

III 1< l I

COINCIDENT WITH EITHER Tavg -- Low-Low 19O 1 1 Tavg/loop 1 Tavg in any 2 loops 1 Tavg in any 3 loops 1,2, 3##

I OR, COINCIDENT WITH Steam Line Pressure-Low 190<1 1 pressure/

loop 1 pressure any 2 loops 1 pressure 1,2,3##

any 3 loops I

SALEM - UNIT 2 3/4 3-15 Amendment No. 121

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO.

FUNCTIONAL UNIT OF CHANNELS CHANNELS TO TRIP MINIMUM CHANNELS OPERABLE APPLICABLE MODES ACTION

4. STEAM LINE ISOLATION

a. Manual 2/steam line 1/steam line 1/operating steam line 1,2,3 23

b. Automatic Actuation Logic 1

2 1,2,3 20

c. Containment Pressure--

High-High 4

2 1/steam line any 2 steam lines 3

1/steam line 1,2,3 16 lCJ9-__111"

d. Steam Flow in Two Steam Lines--High 2/steam line 1,2, 3##

I I

COINCIDENT WITH EITHER Tavg--Low-Low 1 Tavg/loop 1 Tavg in any 2 loops 1 Tavg in any 3 loops 1,2, 3##

I I

OR, COINCIDENT WITH 109Q1' Steam Line Pressure-Low 1 pressure/

loop 1 pressure any 2 loops 1 pressure any 3 loops 1,2, 3##

I I

qnT.rM t7NTT'

,)

3/4 3-9 Amendment No.

+/-2i

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION FUNCTIONAL UNIT TOTAL NO.

OF CHANNELS CHANNELS TO TRIP MINIMUM CHANNELS OPERABLE APPLICABLE MODES ACTION

5. TURBINE TRIP AND FEEDWATER ISOLATION ol

a. Steam Generator Water level--High-High 3/loop 2/loop in any operating loop 2/loop in each operating loop 1,2,3 I

6.

SAFEGUARDS EQUIPMENT CONTROL SYSTEM (SEC)

7.

UNDERVOLTAGE, VITAL BUS

a.

Loss of Voltage

b.

Sustained Degraded Voltage 3

2 3

1,2,3,4 13 14~

1/bus 3/bus 2

2/bus 3

3/bus 1,2,3 1,2,3 SALTEM -

UlNIT 2

3 /A

) -a' I,

I z

V TlUteIUiletlL N'o. i2

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE MODES ACTION FUNCTIONAL UNIT

8. AUXILIARY FEEDWATER

a. Automatic Actuation Logic **

b.

NOT USED

c.

Stm. Gen. Water Level-Low-Low

i.

Start Motor Driven Pumps ii.

Start Turbine Driven Pumps

d.

Undervoltage -

RCP Start Turbine -

Driven Pump

e.

S.I. Start Motor-Driven Pumps

f.

Trip of Main Feedwater Pumps Start Motor-Driven Pumps OF CHANNELS TO TRIP OPERABLE 2

1 2

1,2,3 20 19g 1E)!

I I

3/stm. gen.

4-1/bus 2/stm. gen.

any stm. gen.

2/stm. gen.

any 2 stm.gen.

1/2 x 2 2/stm. gen.

2/stm. gen.

1,2,3 1,2,3 3

1,2 19 See 1 above (All S.I. initiating functions and requirements) 2/pump 1/pump 1/pump 1,2 2

l I

g.

Station Blackout

9.

SEMIAUTOMATIC TRANSFER TO RECIRCULATION

a.

RWST Level Low 4

b.

Automatic Actuation Logic 2

See 6 and 7 above (SEC and UV Vital Bus) 2 1

3 2

1,2,3 1,2,3 16 20 SAT.F.M TTMTT 9

I /A 1-11 T.en-Ient No.1 J U

TABLE 3.3-3 (Continued)

TABLE NOTATION Trip function may be bypassed in this MODE below P-11.

Trip function may be bypassed in this MODE below P-12.

T-:

A.cvizA_.

.f

£ nozn A

At a

izabL.

Applies to Functional Unit 8 items c and d.

The automatic actuation logic includes two redundant solenoid operated vent valves for each Main Steam Isolation Valve.

One vent valve on any one Main Steam Isolation Valve may be isolated without affecting the function of the automatic actuation logic provided the remaining seven solenoid vent valves remain OPERABLE. The isolated MSIV vent valve shall be returned to OPERABLE status upon the first entry into MODE 5 following determination that the vent valve is inoperable.

For any condition where more than one of the eight solenoid vent valves are inoperable, entry into ACTION 20 is required.

ACTION STATEMENTS I

ACTION 13 -

ACTION 14 -

With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1 provided the other channel is OPERABLE.

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed until performance of the next required CHANNEL FUNCTIONAL TEST, provided the inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

ACTION 15 - NOT USED ACTION 16 -

ACTION 17 --

ACTION 18 --

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is demonstrated by CHANNEL CHECK within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; one additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1.

With less than the Minimum Channels OPERABLE, operation may continue provided the containment purge and exhaust valves are maintained closed.

With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SALEM - UNIT 2 3/4 3-22 Amendment No. 121

INSTRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RADIATION MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.1 The radiation monitoring instrumentation channels shown in Table 3.3-E; shall be OPERABLE with their alarm/trip setpoints within the specified limits.

APPLICABILITY: As shown in Table 3.3-6.

ACTION:

a.

With a radiation monitoring channel alarm/trip setpoint exceeding the value shown in Table 3.3-6, adjust the setpoint to within the limit within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels inoperable, take the ACTION shown in Table 3.3-6.

C.

The provisions of Specificatione 3.0.3 end 8.0.1 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.1 Each radiation monitoring instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, SOURCE CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the modes and at the frequencies shown in Table 4.3-3.

SALEM - UNIT 2 3/4 3-38 Amendment No. 206

INSTRUMENTATION MOVABLE INCORE DETECTORS LIMITING CONDITION FOR OPERATION1 3.3.3.2 The movable incore detection system shall be OPERABLE with:

a.

At least 75%* of the detector thimbles,

b.

A minimum of 2 detector thimbles per core quadrant, and

c.

Sufficient movable detectors, drive, and readout equipment to map these thimbles.

APPLICABILITY: When the movable incore detection system is used for:

a.

Recalibration of the excore neutron flux detection system,

b.

Monitoring the QUADRANT POWER TILT RATIO, or

c.

Measurement of FNAH, FQ(Z) and Fxy.

ACTION:

With the movable incore detection system inoperable, do not use the system for the above applicable monitoring or calibration functions. The provisions of Specifications 3.0.3 and 4 are not applicable.

I SURVEILLANCE REQUIREMENTS 4.3.3.2 once per required The movable incore detection system shall be demonstrated OPERABLE at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by normalizing each detector output to be used during its use when for:

a.

Recalibration of the excore neutron flux detection system, or

b.

Monitoring the QUADRANT POWER TILT RATIO, or

c.

Measurement of FN%,

FQ(Z) and Fy.

For Cycle 11, when the number of available movable detector thimbles is greater than 50% but less than 75% of the total, the movable incore system can be considered OPERABLE provided the FNAH, FQ(z) and Fy uncertainties are appropriately adjusted.

Also there should be a minimum of four thimbles available per quadrant, where quadrant -.ncludes both horizontal-vertical and diagonally-bounded quadrants (eight individual. quadrants in total).

SALEM - UNIT 2 3/4 3-42 Amendment No. 212

INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.5 The remote shutdown monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE with readouts displayed external to the control loom.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a.

With the number of OPERABLE remote shutdown monitoring channels less than required by Table 3.3-9, restore the inoperable channel to OPERABLE status within 7 days or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

_ r A

]-

t A

I 1_.._: _:av

_StA

_Z-O.Z L4:Z c

_U

_R_

nt I

p

_ _ i.

SURVEILLANCE REQUIREMENTS 4.3.3.5 Each remote shutdown monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-6.

SALEM -

UNIT 2 3/4 3-4 3

INSTRUMENTATION ACCIDENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.7 The accident monitoring instrumentation channels shown in Table 3.3-11 shall he operable.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a.

As shown in Table 3.3-11.

I o

a: _. I.

n I

- -1. - -

e.

l o

r n

app c---c.

I SURVEILLANCE REQUIREMENTS 4.3.3.7 Each accident monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-11.

SALEM - UNIT 2 3/4 3-50 Amendment No. 206

INSTRUMENTATION RADIOACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.8 The radioactive liquid effluent monitoring instrumentation channels shown in Table 3.3-12 shall be OPERABLE to ensure that the limits of ODCM Control 3.11.1.1 are not exceeded.

APPLICABILITY: At all times.

ACTION:

a.

Not Used

b.

With less than the minimum number of radioactive liquid effluent monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 3.3-12.

Exert best efforts to return the instrument to OPERABLE status within 30 days and, if unsuccessful, explain in the next annual radioactive effluent release report why the inoperability was not corrected in a timely manner.

c.

The provisions of Specificatione 3.0.3 and 0.i-4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.8 Each radioactive liquid effluent monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL CALIBRATION, and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-12.

SALEM - UNIT 2 3/4 3-53 Amendment No.

215

INSTRUMENTATION RADIOACTIVE GASEOUS EFFLUENT OXYGEN MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.9 The radioactive gaseous effluent oxygen monitoring instrumentation channels shown in Table 3.3-13 shall be OPERABLE with their alarm/trip setpoints set to ensure that the limits of Specification 3.11.2.5 are not exceeded.

APPLICABILITY: As shown in Table 3.3-13 ACTION:

a.

With a radioactive gaseous effluent oxygen monitoring instrumentation channel alarm/trip setpoint less conservative than required by the above specification, declare the channel inoperable and take the action shown in Table 3.3-13.

b.

With less than the minimum number of radioactive gaseous effluent cxygen monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 3.3-13.

Exert best efforts to return the instrument to OPERABLE status within 30 days and, if unsuccessful, prepare and submit a special report pursuant to Specification 6.9.2 to explain why the inoperability was not corrected in a timely manner.

c.

The provisions of Specifications 3.0.3 and 99.04, are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.9 Each radioactive gaseous effluent monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL CALIBRATION, AND CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-13.

SALEM -

UN:.T 2 3/4 3-59 Amendment No.

215

INSTRUMENTATION POWER DISTRIBUTION MONITORING SYSTEM LIMITING CONDITION FOR OPERATION (Continued)

APPLICABILTY.- MODE 1, above 25% RATED THERMAL POWER (RTP)

ACTION:

With any cf the operability criteria listed in 3.3.3.14.a, 3.3.3.14.b, or 3.3.-.14.c not met, either correct the deficient operability condition, or declare the PDHS inoperable and use the incore movable detector system, satisfying the OPERABILITY requirements listed in Specification 3.3.3.2, to obtain any required core power distribution measurements.

Increase the measured core peaking factors using the values listed in the COLR for the PDMS inoperable condition.

The provisions of Specificatione 3.0.3 and 9.0.1 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.14.1 The operability criteria listed in 3.3.3.14.a, 3.3.3.14.b, and 3.3.-.14.c shall be verified to be satisfied prior to acceptance of the PDMS core power distribution measurement results.

4.3.3.14.2 Calibration of the PDMS is required:

a. At least once every 180 Effective Full Power Days when the minimum number and core coverage criteria as defined in 3.3.3.14.b.1 and 3.3.3.14.b.2 are satisfied, or

b. At least once every 31 Effective Full Power Days when only the rinimum number criterion as defined in 3.3.3.14.b.3 is satisfied.

Salem - Unit 2 3/4 3-66 Amendment No. 218

REACTOR CCOLANT SYSTEM 3.4.11 STRUCTURAL INTEGRITY ASME CODE CLASS 1, 2 and 3 COMPONENTS LIMITING CONDITION FOR OPERATION 3.4.11.1 The structural integrity of ASME Code Class 1, 2 and 3 components shall be maintained in accordance with Specification 4.4.11.1.

APPLICABILITY:

ALL MODES.

ACTION:

a.

With the structural integrity of any ASME Code Class 1 component(s) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) prior to increasing the Reactor Coolant System temperature more than 500 F above the minimum temperature required by NDT considerations.

b.

With the structural integrity of any ASME Code Class 2 component(s) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) prior to increasing the Reactor Coolant System temperature above 200'F.

c.

With the structural integrity of any ASME Code Class 3 component(s) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) from service.

d.

The previsions of Specification 3.0.4 arc net applicable.

SURVEILLANCE REQUIREMENTS 4.4.11.1 In addition to the requirements of Specification 4.0.5, each Reactor Coolant Pump flywheel shall be inspected per the recommendations of Regulatory Position C.4.b of Regulatory Guide 1.14, Revision 1, August 1975.

4.4.11.2 Augmented Inservice Inspection Program for Steam Generator Channel Heads -

The No. 21 Steam Generator channel head shall be ultrasonically inspected in a selected area during each of the first three refueling outages using the same ultrasonic inspection procedures and equipment used to generate the baseline data.

These inservice ultrasonic inspections shall verify that the cracks observed in the stainless steel cladding prior to operation have not propagated into the base material.

SALEM -

UN:T 2 3/4 4-33 Amendment No. 206 11

PLANT SYSTEMS 3/4.7.8 SEALED SOURCE CONTAMINATION LIMITING CONDITION FOR OPERATION 3.7.8 Each sealed source containing radioactive material either in excess of 100l microcuries of beta and/or gamma emitting material or 5 microcuries of alpha emitting material shall be free of greater than or equal to 0.005 microcuries of removable contamination.

APPLICABILITY: At all times.

ACTION:

a. With a sealed source having removable contamination in excess of the above limits, immediately withdraw the sealed source from use and:

1.

Either decontaminate and repair the sealed source, or

2.

Dispose of the sealed source in accordance with Commission Regulations.

b. The provisions of Specification 3.0.3 and ;.9.

are not applicable.

SURVEILLANZE REQUIREMENTS 4.7.8.1 Test Requirements - Each sealed source shall be tested for leakage and/or contamination by:

a. Thne licensee, or

b. O:her persons specifically authorized by the Commission or an Agreement S:ate.

The test method shall have a detection sensitivity of at least 0.005 microcuries per test sample.

4.7.8.2 Test Frequencies -

Each category of sealed sources (excluding startup sources and fission detectors previously subjected to core flux) shall be tested at the frequency described below.

a. Sources in use - At least once per six months for all sealed sources containing radioactive materials.

SALEM -

UNIT 2 3/4 7-21

PLANT SYSTEMS 3/4.7.11 FUEL STORAGE POOL BORON CONCENTRATION LIMITING CONDITION FOR OPERATION 3.7.11 The fuel storage pool boron concentration shall be = 800 ppm APPLICABILITY:

When fuel assemblies are stored in the fuel storage pool and a fuel storage pcol verification has not been performed since the last movement of fuel assemblies in the fuel storage pool.

ACTION:

With fuel storage pool boron concentration not within limit:

a. Immediately suspend movement of fuel assemblies in the fuel storage pool and

b. Initiate action to:

1. immediately restore fuel storage pool boron concentration to within limit or

2. immediately perform a fuel storage pool verification.

c. The provisions of Specification LCO 3.0.3 ane 8.0.4 are not applicable.

SURVEILLANZE REQUIREMENTS e-.4.7.1l

-Verify the fuel storage pool boron concentration is within limit every 7 days.

PLANT SYSTEMS 3/4.7.12 FUEL ASSEMBLY STORAGE IN THE SPENT FUEL POOL LIMITING CONDITION FOR OPERATION 3.7.12 The combination of initial enrichment, burnup, and Integral Fuel Burnable Absorber (IFBA) of each fuel assembly stored in Region 1 or Region 2, shall be within the acceptable limits described in the surveillance requirements below.

APPLICABILITY:

When any fuel assembly is stored in Region 1 or Region 2 of the spent fuel storage pool.

ACTION:

If the requirements of the LCO are not met:

a. Immediately verify the fuel storage boron concentration meets the requirements of TS 3.7.11 and

b. Immediately initiate action to move the non-complying fuel assembly to a location that complies with the surveillance requirements.

c. The provisions of Specifications 3.0.3 e-nd 3-.0 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.12.1 Prior to storing fuel assemblies in Region 1, verify by administrative means that the fuel assemblies meet one of the following storage constraints:

a. Unirradiated fuel assemblies with a maximum enrichment of 4.25 wt%

U-235 have unrestricted storage.

b. Unirradiated fuel assemblies with enrichments greater than 4.25 wt% U-235 and less than or equal to 5.0 wt% U-235, that do not contain IFBA pins, may only be stored in the peripheral cells facing the concrete wall.

c. Unirradiated fuel assemblies with enrichments (E) greater than 4.25 wt% U-235 and less than or equal to 5.0 wt% U-235, which contain a minimum number of IFBA pins have unrestricted storage.

This minimum number of IFBA pins shall have an equivalent reactivity hold-down which is greater than or equal to the reactivity hold-down associated with N IFBA pins, at a nominal 2.35 mg B-10/linear inch loading (1.5x), determined by the equation below:

N = 42.67 (E -

4.25)

REFUELING OPERATIONS 3/4.9.12 FUEL HANDLING AREA VENTILATION SYSTEM LIMITING CONDITION FOR OPERATION 3.9.12 The Fuel Handling Area Ventilation System shall be OPERABLE with:

a.

Two exhaust fans and one supply fan OPERABLE and operating, and

b.

Capable of maintaining slightly negative pressure in the Fuel Handling Building.

APPLICABILITY:

During movement of irradiated fuel within the Fuel Handling Building ACTION:

a. With no Fuel Handling Area Ventilation System OPERABLE, suspend all operations involvirg movement of fuel within the storage pool until the Fuel Handling Area Ventilation System is restored to OPERABLE status.

b. The provisions of Specificatione 3.0.3 an4.0.1 are not applicable.

SURVEILLANCE REQUIREMENTS 4.9.12The above required ventilation system shall be demonstrated OPERABLE:

a.

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the Fuel Handling Building is maintained at a slightly negative pressure with respect to atmospheric pressure.

b.

At least once per 31 days by verifying both exhaust fans and one supply fan start and operate for at least 15 minutes, if not operating already.

c.

At least once per 18 months by verifying a system flowrate of 19,490 cfm

+/- 10% during system operation.

SALEM - UNIT 2 3/4 9-13 Amendment No. 245

RADIOACTIVE EFFLUENTS LIQUID HOLDUP TANKS*

LIMITING CONDITION FOR OPERATION 3.11.1.4 The quantity of radioactive material contained in each outdoor temporary tank shall be limited to less than or equal to 10 curies, excluding tritium anc.

dissolved or entrained noble gases.

APPLICABILITY: At all times.

ACTION:

a.

With the quantity of radioactive material in any of the above listed tanks exceeding the above limit, immediately suspend all additions of radioactive material to the tank and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tank contents to within the limit.

b.

The provisions of Specification 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.11.1.4 The quantity of radioactive material contained in each outdoor temporary tank shall be determined to be within the above limit by analyzing a representative sample of the tank's contents at least once per 7 days when radioactive materials are being added to the tank.

Tanks included in this Specification are those outdoor temporary tanks that are not surrounded by liners, dikes, or walls capable of holding the tank contents and that do not have tank overflows and surrounding area drains connected to the liquid radwaste treatment system.

SALEM - UNIT 2 3/4 11-7 Amendment No. 28

RADIOACTIVE EFFLUENTS EXPLOSIVE GAS MIXTURE LIMITING CONDITION FOR OPERATION 3.11.2.5 The concentration of oxygen in the waste gas holdup system shall be limited to less than or equal to 2% by volume.

APPLICABILITY: At all times.

ACTION:

a.

With the concentration of oxygen in the waste gas holdup system greater

-:han 2% by volume but less than or equal 4% by volume, reduce the oxygen concentration to the above limits within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

b.

With the concentration of oxygen in the waste gas holdup system greater

-:han 4% by volume immediately suspend all additions of waste gases to the system and reduce the concentration of oxygen to less than or equal to 2%

by volume without delay.

c.

The provisions of Specificatione 3.0.3 and 8.0.1 are not applicable.

SURVEILLAN:E REQUIREMENTS 4.11.2.5 The concentrations of hydrogen and oxygen in the waste gas holdup system shall be determined to be within the above limits by continuously monitoring the waste gases in the waste gas holdup system with the oxygen monitor required OPERABLE by Table 3.3-13. If hydrogen is not measured, the concentration of hydrogen shall be assumed to exceed 4% by volume.

SALEM - UNIT 2 3/4 11-15 Amendment No. 243

ATTACHMENT 3 LR-N06-01 20 LCR S06-04 LIST OF REGULATORY COMMITMENTS The following table identifies those actions committed to by PSEG in this document. Any other statements in this submittal are provided for information only purposes and are not considered to be regulatory commitments. Please direct questions regarding these commitments to James Mallon at (610) 765-5507.

Regulatory Commitment*

Due Date/Event PSEG will establish the Technical Specification Bases for Concurrent with LCO 3.0.4 and SR 4.0.4 as adopted with this license implementation of amendment request.

the amendment PSEG will modify the Technical Specification Bases for TS Concurrent with 3.4.9.3 (Unit 1), 3.4.10.3 (Unit 2), 3.5.3, 3.7.1.2 and 3.8.1 implementation of consistent with this submittal (add Note restricting the use of the amendment 3.0.4b).

PSEG will modify the Technical Specification Bases for TS Concurrent with 3.4.8 (Unit 1) and 3.4.9 (Unit 2) consistent with this submittal implementation of (add Note permitting the use of 3.0.4c).

the amendment

TS numbers applicable to both Salem Unit 1 and Unit 2 TS, except as noted in the Tab e.

ATTACHMENT 4 LR-N06-01 20 LCR S06-04 PROPOSED CHANGES TO TS BASES PAGES The following Technical Specifications Bases for Salem Unit I and Unit 2, Facility Operating License No. DPR-70 and DPR-75, are affected by this change request:

Salem Unit I Technical Slecification Bases 3.0.4 Bases 4.0.4 Bases 3.4.8 Bases 3.4.9.3 Bases 3.5.3 Bases 3.7.1.2 Bases 3.7.11 Bases 3.7.12 Bases 3.8.1.1 Page B 3/4 0-3 B 3/4 0-8 B 3/4 4-5 B 3/4 4-11 B 3/4 5-1 B 3/4 7-2 B 3/4 7-11 B 3/4 7-13 B 3/4 8-1 Salem Unit 2 Technical Specification Bases 3.0.4 Bases 4.0.4 Bases 3.4.9 Bases 3.4.10 Bases 3.5.3 Bases 3.7.1.2 Bases 3.7.11 Bases 3.7.12 Bases 3.8.1.1 Page B 3/4 0-3 B 3/4 0-8 B 3/4 4-6 B 3/4 4-12 B 3/4 5-2 B 3/4 7-2 B 3/47-11 B 3/4 7-13 B 3/4 8-1

A1TACHMENT 4 LCR S06-04 LR-N06-01 20 Insert IB (LCO 3.0.4 BASES)

LCO 3.0.4 establishes limitations on changes in MODES or other specified conditions in the Applicability when an LCO is not met. It allows placing the unit in a MODE or other specified condition stated in that Applicability (e.g., the Applicability desired to be entered) when unit conditions are such that the requirements of the LCO would not be met, in accordance with LCO 3.0.4.a, LCO 3.0.4.b, or LCO 3.0.4.c.

LCO 3.0.4.a allows entry into a MODE or other specified condition in the Applicability with the LCO not met when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time. Compliance with Required Actions that permit continued operation of the unit for an unlimited period of time in a MODE or other specified condition provides an acceptable level of safety for continued operation. This is without regard to the status of the unit before or after the MODE change. Therefore, in such cases, entry into a MODE or other specified condition in the Applicability may be made in accordance with the provisions of the Required Actions.

LCO 3.0.4.b allows entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate.

The risk assessment may use quantitative, qualitative, or blended approaches, and the risk assessment will be conducted using the plant program, procedures, and criteria in place to implement 10 CFR 50.65(a)(4), which requires that risk impacts of maintenance activities to be assessed and managed. The risk assessment, for the purposes of LCO 3.0.4.b, must take into account all inoperable Technical Specification equipment regardless of whether the equipment is included in the normal 10 CFR 50.65(a)(4) risk assessment scope.

The risk assessments will be conducted using the procedures and guidance endorsed by Regulatory Guide 1.182, "Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants." Regulatory Guide 1.182 endorses the guidance in Section 11 of NUMARC 93-01, "Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." These documents address general guidance for conduct of the risk assessment, quantitative and qualitative guidelines for establishing risk management actions, and example risk management actions. These include actions to plan and conduct other activities in a manner that controls overall risk, increased risk awareness by shift and management personnel, actions to reduce the duration of the condition, actions to minimize the magnitude of risk increases (establishment of backup success paths or compensatory measures), and determination that the

ATTACHMENT 4 LCR S06-04 LR-N06-0120 proposed MODE change is acceptable. Consideration should also be given to the probability of completing restoration such that the requirements of the LCO would be met prior to the expiration of ACTIONS Completion Times that would require exiting the Applicability.

LCO 3.0.4.b may be used with single, or multiple systems and components unavailable. NUMARC 93-01 provides guidance relative to consideration of simultaneous unavailability of multiple systems and components.

The results of the risk assessment shall be considered in determining the acceptability of entering the MODE or other specified condition in the Applicability, and any corresponding risk management actions. The LCO 3.0.4.b risk assessments do not have to be documented.

The Technical Specifications allow continued operation with equipment unavailable in MODE 1 for the duration of the Completion Time. Since this is allowable, and since in general the risk impact in that particular MODE bounds the risk of transitioning into and through the applicable MODES or other specified conditions in the Applicability of the LCO, the use of the LCO 3.0.4.b allowance should be generally acceptable, as long as the risk is assessed and managed as stated above. However, there is a small subset of systems and components that have been determined to be more important to risk and use of the LCO 3.0.4.b allowance is prohibited. The LCOs governing these system and components con tain Notes prohibiting the use of LCO 3.0.4.b by stating that LCO 3.0.4.b is not applicable.

LCC) 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met based on an ACTION in the Specification which states LCO 3.0.4.c is applicable. These specific allowances permit entry into MODES or other specified conditions in the Applicability when the associated ACTIONS to be entered do not provide for continued operation for an unlimited period of time and a risk assessment has not been performed. This allowance may apply to all the ACTIONS or to a specific Required Action of a Specification.

The risk assessments performed to justify the use of LCO 3.0.4.b usually only consider systems and components. For this reason, LCO 3.0.4.c is typically applied to Specifications that describe values and parameters (e.g., Containment Air Temperature, Containment Pressure, Moderator Temperature Coefficient),

and may be applied to other Specifications based on NRC plant-specific approval.

The provisions of this Specification should not be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.

ATTACHMENT 4 LCR S06-04 LR-N06-01 20 The provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that result from any unit shutdown. In this context, a unit shutdown is defined as a change in MODE or other specified condition in the Applicability associated with transitioning from MODE 1 to MODE 2, MODE 2 to MODE 3, MODE 3 to MODE 4, and MODE 4 to MODE 5.

Upon entry into a MODE or other specified condition in the Applicability with the LCC) not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the unit is not within the Applicability of the Technical Specification.

Surveillances do not have to be performed on the associated inoperable equipment (or on variables outside the specified limits), as permitted by SR 4.0.1.

Therefore, utilizing LCO 3.0.4 is not a violation of SR 4.0.1 or SR 4.0.4 for any Sur/eillances that have not been performed on inoperable equipment. However, SRs must be met to ensure OPERABILITY prior to declaring the associated equipment OPERABLE (or variable within limits) and restoring compliance with the affected LCO.

ATTACHMENT 4 LCR S06-04 LR-N06-01 20 INSERT 2B (SR 4.0.4 BASES)

SR 4.0.4 establishes the requirement that all applicable SRs must be met before entry into a MODE or other specified condition in the Applicability.

This Specification ensures that system and component OPERABILITY requirements and variable limits are met before entry into MODES or other specified conditions in the Applicability for which these systems and components ensure safe operation of the unit. The provisions of this Specification should not be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.

A provision is included to allow entry into a MODE or other specified condition in the Applicability when an LCO is not met due to Surveillance not being met in accordance with LCO 3.0.4.

However, in two certain circumstances, failing to meet an SR will not result in SR 4.0.4 restricting a MODE change or other specified condition change:

(1) When a system, subsystem, division, component, device or variable is inoperable or outside its specified limits, the associated SR(s) are not required to be performed, per SR 4.0.1, which states that surveillances do not have to be performed on inoperable equipment. When equipment is inoperable, SR 4.0.4 does not apply to the associated SR(s) since the requirement for the SR(s) to be performed is removed. Therefore, failing to perform the Surveillance(s) within the specified Frequency does not result in an SR 4.0.4 restriction to changing MODES or other specified conditions of the Applicability. However, since the LCO is not met in this instance, LCO 3.0.4 will govern any restrictions that may (or may not) apply to MODE or other specified condition changes.

(2) SR 4.0.4 does not restrict changing MODES or other specified conditions of the Applicability when a Surveillance has not been performed within the specified Frequency, provided the requirement to declare the LCO not met has been delayed in accordance with SR 4.0.3.

The provisions of SR 4.0.4 shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of SR 4.0.4 shall not prevent changes in MODES or other spec ified conditions in the Applicability that result from any unit shutdown. In this context, a unit shutdown is defined as a change in MODE or other specified condition in the Applicability associated with transitioning from MODE 1 to MODE 2, MODE 2 to MODE 3, MODE 3 to MODE 4, and MODE 4 to MODE 5.

ATTACHMENT 4 LCR S06-04 LR-N06-01 20 The precise requirements for performance of SRs are specified such that exceptions to SR 4.0.4 are not necessary. The specific time frames and conditions necessary for meeting the SRs are specified in the Frequency, in the Surjeillance, or both. This allows performance of Surveillances when the prerequisite condition(s) specified in a Surveillance procedure require entry into the MODE or other specified condition in the Applicability of the associated LCO prior to the performance or completion of a Surveillance. A Surveillance that could not be performed until after entering the LCO's Applicability would have its Frequency specified such that it is not "due" until the specific conditions needed are met. Alternately, the Surveillance may be stated in the form of a Note, as not required (to be met or performed) until a particular event, condition, or time has been reached. Further discussion of the specific formats of SRs' annotation is found in Section 1.4, Frequency.

ATTACHMENT 4 LCR S06-04 LR-N06-01 20 INSERT 3B (LCO 3.4.8 (Unit 1), LCO 3.4.9 (Unit 2) - RCS SPECIFIC ACTIVITY BA.SES)

LCO 3.0.4.c is applicable. This allowance permits entry into the applicable MODE(S) while relying on the ACTIONS.

ATT ACHMENT 4 LCR S06-04 LR-N06-01 20 INSERT 4B (LCO 3.4.9.3 (Unit 1), 3.4.10.3 (Unit 2), OVER PRESSURE PROTECTION SYSTEM BASES)

LCO 3.0.4.b is not applicable to an inoperable LTOP system when entering MODE 4. There is an increased risk associated with entering MODE 4 from MODE 5 with an inoperable LTOP system. The provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LOC) not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

ATTACHMENT 4 LCR S06-04 LR-N06-01 20 INSERT 5B (LCO 3.5.3, ECCS BASES)

LCO 3.0.4.b is not applicable to an inoperable ECCS high head subsystem when entering MODE 4. There is an increased risk associated with entering MODE 4 from MODE 5 with an inoperable ECCS high head subsystem. The provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

ATTACHMENT 4 LCR S06-04 LR-N06-01 20 INSERT 6B (LCO 3.7.1.2, AFWSYSTEM BASES)

LCO 3.0.4.b is not applicable to an inoperable AFW train. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an AFW train inoperable. The provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

ATFACHMENT 4 LCR S06-04 LR-N06-01 20 INSERT 7B (LCO 3.8.1.1, AC SOURCES BASES)

LCO 3.0.4.b is not applicable to an inoperable DG. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable DG. The provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

APPLICABILITY BASES return to POWER operation, a penalty is not incurred by having to reach a lower MODE of operation in less than the total time allowed.

The same principle applies with regard to the allowable outage time limits of the ACTION requirements, if compliance with the ACTION requirements for one specification results in entry into a MODE or condition of operation for another specification in which the requirements of the Limiting Condition for Operation are not met.

If the new specification becomes applicable in less time than specified, the difference may be added to the allowable outage time limits of the second specification.

However, the allowable outage time limits of ACTION requirements for a higher MODE of operation may not be used to extend the allowable outage time that is applicable when a Limiting Condition for Operation is not met in a lower MODE of operation.

The shutdown requirements of Specification 3.0.3 do not apply in MODES 5 and 6, because the ACTION requirements of individual specifications define the remedial measures to be taken.

Specification 3.0.4 e tablishes lPitations on MODE changes when r Limitlng Con 10 met.

It pr cludes placing the facility in higher MODE of operation when the requirements for a Limiting Condition for Op ration are not met and continued noncompliance to ahese conditions would result '

a shutdown to comply with the ACTION requirements.f a change in MODES were permit ed.

The purpose of this specification is to ensu e that facility operation is n initiated or that higher MODES of operation a Vnot entered when corrective a ion is being taken to obtain compliance with a sp cification by restoring equipmet to OPERABLE status or parameters to specified li its.

Compliance with ACTION re uirements that permit continued operation of th facility for an unlimited perid of time provides an acceptable level of safe y for continued operation witho t regard to the status of the plant before or aft r a MODE change.

Therefore, in this case, entry into anl OPERATIONA:; MODE or oth r specified condition may be -de in accordance with the provisions of the ACTI N requirements.

The provision of this specification shDuld not, however, be imt preted as endorsing the failur to exercise good practice in restoring systems o components to OPERABLE status efore plant startup.

When a shutdown i required to comply with ACTION requirements, the provisions of Specification 3

.4 do not apply because they wo ld delay placing the facility in a lower MODE of peration.

As used in is Specification, the word "shut own" encompasses entry into a lower operationa. mode and its meaning is not lim ed only to movement into modes containing he word shutdown.

Inet 1

j SALEM - UNIT 1 B 3/4 0-3 Amendment No. 131

APPLICABILITY BASES Insert 2B Specification 4.0.4 estab h

the requirement that all applicable surveillanc mus e met beore entry mt an OPERATIONAL MODE or ot er condition of operation specified in the Applicability statement.

The purpose of this specification is to ensure that system and co onent OPERABILITY requirem ts or parameter limits are met before entry into a MODE r condition for which these systems and components ensure safe operation of the f cility. This provision appl s to changes in OPERATIONAL MODES or other specif d conditions associated wit plant shutdown as well as startup.

/

Under the -rovisons of this specification, th applicable Surveillance Requirements must be perform d within the specified surveil ance interval to ensure that the Limiting Condit ons for Operation are met durng initial plant startup or following a plant outage.

When a shutd n is required to comply with TION requirements, the provisions of Specificati n 4.0.4 do not apply because ths could delay placing the facility in a lower MODE of operation.

Specification 4.0.5 establishes the re irement that inservice inspection of ASME Code Class 1, 2, and 3 components and inservice testing of ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with a periodically updated version of Section XI of the ASME Boiler and Pressure Vessel Code and Addenda as required by 10 CFR 50.55a.

These requirements apply except when relief has been provided in writing by the Commission.

This specification includes a clarification of the frequencies for performing the inservice inspection and testing activities required by Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda.

This clarification is provided to ensure consistency in surveillance intervals throughout the Technical Specifications and to remove any ambiguities relative to the frequencies for performing the required inservice inspection and testing activities.

Under the *:erms of this specification, the more restrictive requirements of the Technical :Specifications take precedence over the ASME Boiler and Pressure Vessel Code and applicable Addenda.

The requirements of Specification 4.0.4 to perform surveillance activities before entry into an OPERATIONAL MODE or other specified condition takes precedence over the ASME Boiler and Pressure Vessel Code provision which allows pumps and valves to be tested up to one week after return to normal operation.

The Technical Specification definition of OPERABLE does not allow a grace period before a component, that is not capable of performing its specified function, is declared inoperable and takes precedence over the ASME Boiler and Pressure Vessel Code provision which allows a valve to be incapable of performing its specified function for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months before being declared inoperable.

SALEM -

UN:.'T I B 3/4 0-8 Amendment No. 256

REACTOR COOLANT SYSTEM BASES 3/4.4.8 SPECIFIC ACTIVITY The limitations on the specific activity of the primary coolant ensure that the resulting 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months doses at the site boundary will not exceed an appropriately small fraction of Part 100 limits following a steam generator tube rupture accident in conjunction with an assumed steady state primary-to-secondary steam generator leakage rate of 1.0 GPM.

The values for the limits on specific activity represent interim limits based upon a parametric evaluation by the NRC of typical site locations.

These values are conservative in that specific site parameters of the Salem site, such as site boundary location and meteorological conditions, were not considered in this evaluation.

The NRC is finalizing site specific criteria which will be used as the basis for the reevaluation of the specific activity limits of this site.

This reevaluation may result in higher limits.

Reducing Tavg to <5000 F prevents the release of activity should a steam generator tube rupture occur since the saturation pressure of the primary coolant is below the lift pressure of the atmospheric steam relief valves.

The surveillance requirements provide adequate assurance that excessive specific activity levels in the primary coolant will be detected in sufficient time to take corrective action.

Information obtained on iodine spiking will be used to assess the parameters associated with spiking phenomena.

A reduction in frequency of isotopic analyses following power changes may be permissible if justified by the data obtained.

Insert 3B SALEM - UN::T 1 B 3/4 4-5 Amendment No. 225

REACTOR CCOLANT SYSTEM BASES Finally, the new 10CFR50 rule which addresses the metal temperature of the closure head flange is considered. This 10CFR50 rule states that the metal temperature of the closure flange regions must exceed the material RTNDT by at least 1200F for normal operation when the pressure exceeds 20 percent of the preservice hydrostatic test pressure (621 psig for Salem). Table B3/4 4-1 indicates that the limiting RTNDr of 280 F occurs in the closure head flange of Salem Unit 1, and the minimum allowable temperature of this region is 1480 F at pressures greater than 621 psig. These limits do not affect Figures 3.4-2 and 3.4-3.

Although the pressurizer operates in temperature ranges above those for which there is reason for concern of non-ductile failure, operating limits are provided to assure compatibility of operation with the fatigue analysis performed in accordance with the ASME Code requirements.

The OPERABILITY of two POPS or an RCS vent opening of greater than 3.14 square inches ensures that the RCS will be protected from pressure transients which could exceed the limits of Appendix G to 10 CFR Part 50 when one or more of the RCS cold legs are less than or equal to 312'F. Either POPS has adequate relieving capability to protect the RCS from overpressurization when the transient is limited to either (1) the start of an idle RCP with the secondary water temperature of the steam generator less than or equal to 50_F above the RCS cold leg temperatures, or (2) the start of an intermediate head safety injection pump and its injection into a water solid RCS, or the start of a high head safety injection pump in conjunction with a running positive displacement pump and its injection into a water solid RCS.

The minimum electrical power sources required to assure POPS operability (based on POPS meeting the single failure criteria) consist of a normal (via offsite power) and an emergency (via batteries) power source for each train of POPS.

Emergency diesel generators are not required for POPS to meet single failure criteria and therefore are not required for POPS OPERABILITY.

Insert 4B SALEM - UN--T I B 3/4 4-11 Revised by letter dated 9/12/01

3/4.5 EMERGENCY CORE COOLING SYSTEMS BASES 3/4.5.1 ACCUMULATORS The OPERAEILITY of each RCS accumulator ensures that a sufficient volume of borated water will be immediately forced into the reactor core through each of the colc. legs in the event the RCS pressure falls below the pressure of the accumulators. This initial surge of water into the core provides the initial cooling mechanism during large RCS pipe ruptures.

The limits on accumulator volume, boron concentration and pressure ensure that the assumptions used for accumulator injection in the safety analysis are met.

The accumulator power operated isolation valves are considered to be "operating bypasses" in the context of IEEE Std. 279-1971, which requires that bypasses of a protective function be removed automatically whenever permissive conditions are not met. In addition, as these accumulator isolation valves fail to meet single failure criteria, removal of power to the valves is required.

The limits for operation with an accumulator inoperable for any reason except an isolation valve closed minimizes the time exposure of the plant to a LOCA event occurring concurrent with failure of an additional accumulator which may result in unacceptable peak cladding temperatures. If a closed isolation valve cannot be immediately opened, the full capability of one accumulator is not available and prompt action is required to place the reactor in a mode where this capability is not required.

3/4.5.2 and 3/4.5.3 ECCS SUBSYSTEMS The OPERABILITY of two independent ECCS subsystems ensures that sufficient emergency core cooling capability will be available in the event of a LOCA assuming the loss of one subsys7:em through any single failure consideration. Either subsystem operating in conjunction with the accumulators is capable of supplying sufficient core cooling to limit the peak cladding temperatures within acceptable limits for all postulated break sizes ranging from the double ended break of the largest RCS cold leg pipa downward. In addition, each ECCS subsystem provides long term core cooling capability in the rec:rculation mode during the accident recovery period.

The limitation for a maximum of one safety injection pump or centrifugal charging pump to be OPERABLE and the Surveillance Requirement to verify all safety injection pumps except the allowed OPERABLE pump to be inoperable below 312'F provides assurance that a mass addition pressure transient can be relieved by the operation of a single POPs relief valve.

Insert 5B jl 71 1I SALEM - UNIT 1 B 3/4 5-1 Amendment No. 94

PLANT SYSTEMS BASES For three inoperable main steam safety valves in one or more steam generators, thermal reactor power must be reduced in conjunction with a reduction in the Pcwer Range Neutron Flux High trip setpoint to prevent overpressurization of the main steam system.

The transient analysis assumes that the MSSVs will start to open at the lift setpoint with 3% allowance for setpoint tolerance.

In addition, the analysis accounts for accumulation by including a 5 psi ramp for the valve to reach its fully open position.

Inoperable MSSVs are assumed to be those with the lowest lift setting.

Surveillance testing as covered in Table 4.7-1 allows a +/- 3% lift setpoint tolerance.

However, to allow for drift during subsequent operation, the valves must be reset to within +/- 1% of the lift setpoint following testing.

3/4.7.1.2 AUXILIARY FEEDWATER SYSTEM The OPERABILITY of the auxiliary feedwater system ensures that the Reactor Coolant System can be cooled down to less than 3500 F from normal operating conditions in the event of a total loss of off-site power.

Verifying that each Auxiliary Feedwater (AFW) pump's developed head at the flow test point is greater than or equal to the required minimum developed head ensures that the AFW pump performance has not degraded during the cycle, and that the assumptions made in the accident analysis remain valid. Flow and differential head are normal tests of centrifugal pump performance required by Section XI of the ASME Code.

Because it is undesirable to introduce cold AFW into the steam generators while operating, the test is performed on recirculation flow.

This test confirms one point on the pump design curve (head vs flow curve), and is indicative of pump performance. Inservice testing confirms pump operability, trends performance and detects inzipient failures by indication of pump performance.

The flow path to each steam generator is ensured by maintaining all manual maintenance valves locked open.

A spool piece consisting of a length of pipe may be used as an equivalent to a locked open manual valve.

The manual valves in the flow path are: 1AF1, llAF3, 12AF3, 13AF3, 1lAF10, 12AF10, 13AF10, 14AF10, 11AF20, 12AF20,

13AF20, 14AF20,

11AF22, 12AF22,

13AF22, 14AF22,

11AF86, 12AF86,

13AF86, and 14AF86.

lInsert 6B 3/4.7.1.3 AUXILIARY FEED STORAGE TANK The OPERABILITY of the auxiliary feed storage tank with the minimum water volume ensures that sufficient water is available to maintain the RCS at HOT STANDBY conditions for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months with steam discharge to the atmosphere concurrent with total loss of of:f-site power. The contained water volume limit includes an allowance for water not usable because of tank discharge line location or other physical characteristics.

SALEM -

UN':.T I B 3/4 7-2 Amendment No. 244

PLANT SYSTEMS BASES 3/4.7.11 FUEL STORAGE POOL BORON CONCENTRATION (continued)

The Required Actions are modified indicating that LCO 3.0.3 and LCO.O.1-9.4e does not apply.

Storage of fuel assemblies and the boron concentration in the spent fuel storage pool are independent of reactor operation.

Therefore TS 3/4 3.7.11 and TS 3/4 3.7.12 include the exception to LCO 3.0.3 and LCO 3.9.l to preclude an inappropriate reactor shutdown &no clorlfy that L7O ;..i doos not impoose md6e el fongr fzons these r;.e-fiootiooo.

When the concentration of boron in the fuel storage pool is less than required, immediate action must be taken to preclude the occurrence of an accident or to mitigate the consequences of an accident in progress.

This is most efficiently achieved by immediately suspending the movement of fuel assemblies.

The concentration of boron is restored simultaneously with suspending movement of fuel assemblies.

Alternatively, beginning a verification of the fuel storage pool fuel locations, to ensure proper locations of the fuel, can be performed.

However, prior to resuming movement of fuel assemblies, the concentration of boron must be restored.

This does not preclude movement of a fuel assembly to a safe position.

If the LCO is not met while moving fuel assemblies in the spent fuel pool while in MODE 5 or 6, LCO 3.0.3 would not be applicable.

If moving fuel assemblies in spent fuel pool while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation.

Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown or imoor mode change eortrootio~@.

This SR verifies that the concentration of boron in the fuel storage pool is within the required limit.

As long as this SR is met, the analyzed accidents are fully addressed.

The 7 day Frequency is appropriate because no major replenishment of pool water is expected to take place over such a short period of time.

Salem - Unit 1 B 3/4 7-1 1 Amendment No. 262

ZSnem Enit 1 B

3,4 7 12 Af._ncrnnt No.262 PLANT SYSIEMS BASES 3/4.7.12 FUEL ASSEMBLY STORAGE IN THE SPENT FUEL POOL (CONTINUED)

The restrictions on the placement of fuel assemblies within the spent fuel pool in accordance with TS 3/4.7.12, in the accompanying LCO, ensures the keff of the spent fuel storage pool will always remain < 0.95, assuming the pool to be flooded with unborated water.

This LCO applies whenever any fuel assembly is stored in Region 1 or Region 2 of the fuel storage pool.

The Required Actions are modified indicating that LCO 3.0.3 and LOC 3.0.4 does not apply.

Storage of fuel assemblies and the boron concentration in the spent fuel storage pool are independent of reactor operation. Therefore TS 3/4.3.7.11 and TS 3/4.3.7.12 include the exception to LCO 3.0.3 and LCO

.0.i to preclude an inappropriate reactor shutdown en4 clarify that LCO

.0.9 do: : not impose Ms6:

<voe

...zt:0t>i.:

for thor:

ejoo fiortlono. When the configuration of fuel assemblies stored in Region 1 or Region 2 of the spent fuel storage pool is not in accordance with TS 3,'4.7.12, the immediate action is to initiate action to make the necessary fuel assembly movement(s) to bring the configuration into compliance with TS 3/4.7.12.

If unable to move fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not be applicable. If unable to move fuel assemblies while in MODE 1, 2, 3, or 4, the action is independent of reactor operation.

Therefore, inability to move fuel assemblies is not sufficient reason to require a reactor shutdown or

"Ooc modec The SR verifies by administrative means that the initial enrichment and burnup of the fuel assembly is in accordance with TS 3/4.7.12 in the accompanying LCO.

Salem - Unit 1 B 3/4 7-13 Amendment No.262

3/4.8 ELECTRICAL POWER SYSTEMS BASES 3/4.8.1 and 3/4.8.2 A.C. SOURCES AND ONSITE POWER DISTRIBUTION SYSTEMS The OPERABILITY of the A.C. and D.C power sources and associated distribution systems during operation ensures that sufficient power will be available to supply the safety related equipment required for 1) the safe shutdown of the facility, and

2) the mitigation and control of accident conditions within the facility.

The minimum specified independent and redundant A.C. and D.C. power sources and distribution systems satisfy the requirements of General Design Criterion 17 of Appendix "A" to 10 CFR Part so This should be inserted Insert 7 in the next paae The ACTI r the levels of degradation of the power sources provide restriction upon continued facility operation commensurate with the level of degradation.

The OPERABILITY of the power analyses and are based upon maintaining at least two independent sets of onsite A.C. and D.C. power sources and associated distribution systems OPERABLE during accident conditions coincident with an assumed loss of offsite power and single failure of one onsite A.C. source.

When a system or component is determined to be inoperable solely because its emergency power source is inoperable, or solely because its normal power source is inoperable, it may still be considered OPERABLE, provided the appropriate Actions of 3.8.1.1.a.2, b.2 or d.2 are satisfied.

Action 3.8.1.1.a.2, which only applies if the train cannot be powered from. an offsite source, is intended to provide assurance that an event coincident with a single failure of the associated DG will not result in a complete loss of safety function of critical redundant required systems.

Failure of a single offsite circuit will generally not, by itself, cause any equipment to lose normal AC power.

Action 3.8.1.1.b.2 is intended to provide assurance that a loss of offsite power, during the period that a DG is inoperable, does not result in a complete loss of safety function of critical systems. Action 3.8.1.1.d.2, which applies when two offsite circuits are inoperable, is intended to provide assurance that an event with a coincident single failure will not result in a complete loss of redundant required safety functions.

These systems are powered from the redundant AC electrical power train. This includes motor driven auxiliary feedwater pumps. Single train systems, such as turbine driven auxiliary feedwater pumps, may not be included. Redundant required system or component failures consist of inoperable equipment associated with a train, redundant to the train that has an inoperable DG or offsite power.

The completion time for these actions is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This completion time also allows for an exception to the normal "time zero" for beginning the allowed outage time clock, starting only on discovery that both:

a. One train has no offsite power supplying its loads, one DG is inoperable or two required offsite circuits are inoperable; and

b. A required system or component on the other train is inoperable.

SALEM - UN::T 1 B 3/4 8-1 Amendment No.253

APPLICABILITY BASES return to POWER operation, a penalty is not incurred by having to reach a lower MODE of operation in less than the total time allowed.

The same principle applies with regard to the allowable outage time limits of the ACTION requirements, if compliance with the ACTION requirements for one specification results in entry into a MODE or condition of operation for another specification in which the requirements of the Limiting Condition for Operation are not met.

If the new specification becomes applicable in less time than specified, the difference may be added to the allowable outage time limits of the second specification.

However, the allowable outage time limits of ACTION requirements for a higher MODE of operation may not be used to extend the allowable outage time that is applicable when a Limiting Condition for Operation is not met in a lower MODE of operation.

The shutdown requirements of Specification 3.0.3 do not apply in MODES 5 and 6, because the ACTION requirements of individual specifications define the remedial measures to be taken.

S ecification 3.0.4 e tablishes limita ions on MODE changes when Limiting Condt r Operation is not met.

It preclu s placing the facility in higher MODE cf operation when the requirements for Limiting Condition for Opration are not met and continued noncompliance to the conditions would result a shutdown to comply with the ACTION requirements if a/change in MODES were permi ed.

The purpose of this specification is to ensure hat facility operation is t initiated or that higher MODES of operation are t entered when corrective tion is being taken to obtain compliance with a spec ication by restoring equip nt to OPERABLE status or parameters to specified limi s. Compliance with ACTION r quirements that permit continued operation of the acility for an unlimited per od of time provides an acceptable level of safety for continued operation with ut regard to the status of the plant before or after/a MODE change.

Therefore, i this case, entry into an OPERATIONAL MODE or othe specified condition may be ade in accordance with the provisions of the ACTIO requirements.

The provisi s of this specification should not, however, be inter eted as endorsing the fail re to exercise good practice in restoring systems or c mponents to OPERABLE statu before plant startup.

When a shutdown is re uired to comply with ACTI N requirements, the provisions of Specification 3.0.4 o not apply because they ould delay placing the facility in a lower MODE of opera ion.

As used in this ecification, the word "s tdown" encompasses entry into a lower operationaL mo and its meaning is not 1 ited only to movement into modes containing t word shutdown.

Insert 1B SALEM - UNIT 2 B 3/4 0-3 Amendment No. 110

APPLICABILITY BASES Specification 4.0.4 es ablishes the equirement that all ap icable surveillano us e met beTore entry into an 0 RATIONAL MODE or other ondition of operation specified in the Applicability st tement.

The purpose of his specification is to ensure that system and component OPERABILITY requirement or parameter limits are met before entry into a MODE or co ition for which these s tems and components ensure safe operation of the facilit.

This provision applie to changes in OPERATIONAL MODES or cther specified co itions associated with p ant shutdown as well as startup.//

Under the provisions o this specification, the pplicable Surveillance Requirements must be performed wit in the specified surveil ance interval to ensure that the Limiting Conditions or Operation are met durng initial plant startup or following a plant outage.

When a shutdown i required to comply wit ACTION requirements, the provisions of Specification 4..4 do not apply because this could delay placing the facility wer MODE of o eration.

Insert 2B Specification 4.0.5 establishes the requirement that inservice inspection of ASME Code Class 1, 2, and 3 components and inservice testing of ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with a periodically updated version of Section XI of the ASME Boiler and Pressure Vessel Code and Addenda as required by 10 CFR 50.55a.

These requirements apply except when relief has been provided in writing by the Commission.

This specification includes a clarification of the frequencies for performing the inservice inspection and testing activities required by Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda.

This clarification is provided to ensure consistency in surveillance intervals throughout the Technical Specifications and to remove any ambiguities relative to the frequencies for performing the required inservice inspection and testing activities.

Under the :erms of this specification, the more restrictive requirements of the Technical Specifications take precedence over the ASME Boiler and Pressure Vessel Code and applicable Addenda.

The requirements of Specification 4.0.4 to perform surveillance activities before entry into an OPERATIONAL MODE or other specified condition takes precedence over the ASME Boiler and Pressure Vessel Code provision which allows pumps and valves to be tested up to one week after return to normal operation.

The Technical Specification definition of OPERABLE does not allow a grace period before a component, that is not capable of performing its specified :-unction, is declared inoperable and takes precedence over the ASME Bailer and Pressure Vessel Code provision which allows a valve to be incapable of performing its specified function for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months before being declared inoperable.

SALEM - UNI:T 2 B 3/4 0-8 Amendment No. 237

REACTOR CCOLANT SYSTEM BASES 3/4.4.9 SPECIFIC ACTIVITY The limitations on the specific activity of the primary coolant ensure that the resulting 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months doses at the site boundary will not exceed an appropriately small fraction of Part 100 limits following a steam generator tube rupture accident in conjunction with an assumed steady state primary-to-secondary steam generator leakage rate of 1.0 GPM.

The values for the limits on specific activity represent interim limits based upon a parametric evaluation by the NRC of typical site locations.

These values are conservative in that specific site parameters of the Salem site, such as site boundary location and meteorological conditions, were not considered in this evaluation.

The NRC is finalizing site specific criteria which will be used as the basis for the reevaluation of the specific activity limits of this site.

This reevaluation may result in higher limits.

Reducing T avg to less than 5000 F prevents the release of activity should a steam generator tube rupture occur since the saturation pressure of the primary coolant is below the lift pressure of the atmospheric steam relief valves.

The surveillance requirements provide adequate assurance that excessive specific activity levels in the primary coolant will be detected in sufficient time to take corrective action.

Information obtained on iodine spiking will be used to assess the parameters associated with spiking phenomena.

A reduction in frequency of isotopic analyses following power changes may be permissible if justified by the data obtained.

Insert 3B SALEM - UNIT 2 B 3/4 4-6 Amendment No.

206

REACTOR COOLANT SYSTEM BASES Finally, the new 10CFR50 rule which addresses the metal temperature of the closure head flange regions is considered. This 10CFR50 rule states that the metal temperature of the closure flange regions must exceed the material RTNDT by at least 1200 F for normal operation when the pressure exceeds 20 percent of the preservice hydrostatic test pressure (621 psig for Salem). Table B3/4.4-1 indicates that the limiting RTNDT of 280 F occurs in the closure head flange of Salem Un't 1 Salem Unit 2, and the minimum allowable temperature of this region is 1480 F at pressures greater than 621 psig. These limits do not affect Figures 3.4-2 and 3.4-3.

Although the pressurizer operates in temperature ranges above those for which there is reason for concern of non-ductile failure, operating limits are provided to assure compatibility of operation with the fatigue analysis performed in accordance with the ASME Code requirements.

The OPERABILITY of two POPSs or an RCS vent opening of greater than 3.14 square inches ensures that the RCS will be protected from pressure transients which could exceed the limits of Appendix G to 10 CFR Part 50 when one or more of the RCS cold legs are less than or equal to 312'F. Either POPS has adequate relieving capability to protect the RCS from overpressurization when the transient is limited to either (1) the start of an idle RCP with the secondary water temperature of the steam generator less than or equal to 500 F above the RCS cold leg temperatures, or (2) the start of an Intermediate Head Safety Injection pump and its injection into a water solid RCS, or the start of a High Head Safety Injection pump in conjunction with a running Positive Displacement pump and its injection into a water solid RCS.

The minimum electrical power sources required to assure POPS operability (based on POPS meeting the single failure criteria) consist of a normal (via offsite power) and an emergency (via batteries) power source for each train of POPS.

Emergency diesel generators are not required for POPS to meet single failure criteria and therefore are not required for POPS OPERABILITY.

Insert 4B SALEM - UNZT 2 B 3/4 4-12 Revised by letter dated 9/12/01

EMERGENCY CORE COOLING SYSTEMS BASES ECCS SUBSYSTEMS (Continued)

With the RCS temperature below 350'F, one OPERABLE ECCS subsystem is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the limited core cooling requirements.

The limitation for a maximum of one safety injection pump or one centrifugal charging pump to be OPERABLE and the Surveillance requirement to verify all safety injection pumps except the allowed OPERABLE safety injection pump to be inoperable below 3120 1 provides assurance that a mass addition pressure transient can be relieved by the operation of a single POPS relief valve.

Insert 5B I J The surveillance requirements, which are provided to ensure the OPERABILITY of each component, ensure that, at a minimum, the assumptions used in the safety analyses are met and that subsystem OPERABILITY is maintained. The safety analyses make the assumptions with respect to:

1) both the maximum and minimum total system resistance, and 2) both the maximum and minimum branch injection line resistance.

These resistances, in conjunction with the ranges of potential pump performance, are used to caLculate the maximum and minimum ECCS flow assumed in the safety analyses.

The maximum and minimum flow surveillance requirements in conjunction with the maximum and minimum pump performance curves ensures that the assumptions of total system resistance and the distribution of that system resistance among the various paths are met.

The maximum total pump flow surveillance requirements ensure the pump runout limits of 560 gpm for the centrifugal charging pumps and 675 gpm for the safety injection pumps are not exceeded.

Due to the effect of pump suction boost alignment, the runout limits for the surveillance criteria are < 554 gpm for C/SI pumps, < 664 gpm for SI pumps in cold leg alignment and < 654 gpm for SI pumps in hot leg alignment.

The surveillance requirement for the maximum difference between the maximum and minimum individual injection line flows ensure that the minimum individual injection line resistance assumed for the spilling line following a LOCA is met.

3/4.5.4 SEAL INJECTION FLOW The Reactor Coolant Pump (RCP) seal injection flow restriction limits the amount of ECCS flow that would be diverted from the injection path following an ECCS actuation.

This limit is based on safety analysis assumptions, since RCP seal injection flow is not isolated during Safety Injection (SI).

SALEM - UNIT 2 B 3/4 5-2 Amendment No.4-59, 189

PLANT SYSTEMS BASES For three inoperable main steam safety valves in one or more steam generators, thermal reactor power must be reduced in conjunction with a reduction in the Pcwer Range Neutron Flux High trip setpoint to prevent overpressurization of the main steam system.

The transient analysis assumes that the MSSVs will start to open at the lift setpoint with 3% allowance for setpoint tolerance.

In addition, the analysis accounts for accumulation by including a 5 psi ramp for the valve to reach its fully open position.

Inoperable MSSVs are assumed to be those with the lowest lift setting.

Surveillance testing as covered in Table 3.7-4 allows a +/- 3% lift setpoint tolerance.

However, to allow for drift during subsequent operation, the valves must be reset to within +/- 1% of the lift setpoint following testing.

3/4.7.1.2 AUXILIARY FEEDWATER SYSTEM The OPERABILITY of the auxiliary feedwater system ensures that the Reactor Coolant System can be cooled down to less than 350'F from normal operating conditions in the event of a total loss of offsite power.

Verifying that each Auxiliary Feedwater (AFW) pump's developed head at the flow test point is greater than or equal to the required minimum developed head ensures that the AFW pump performance has not degraded during the cycle, and that the assumption made in the accident analysis remain valid. Flow and differential head are normal tests of centrifugal pump performance required by Section XI of the ASME Code.

Because it is undesirable to introduce cold AFW into the steam generators while operating, the test is performed on recirculation flow.

This test confirms one point on the pump design curve (head vs flow curve), and is indicative of pump performance.

Inservice testing confirms pump operability, trends performance and detects incipient failures by indication of pump performance.

The flow path to each steam generator is ensured by maintaining all manual maintenance valves locked open.

A spool piece consisting of a length of pipe ray be used as an equivalent to a locked open manual valve.

The manual valves in the flow path are: 2AF1, 21AF3, 22AF3, 23AF3, 21AF10, 22AF10, 23AF10, 24AF10, 21AF20, 22AF20, 23AF20, 24AF20, 21AF22, 22AF22, 23AF22, 24AF22, 21AF86, 22AF86, 23AF86, and 24AF86.

Insert 6B l_

3/4.7.1.3 AUXILIARY FEED STORAGE TANK The OPERABILITY of the auxiliary feed storage tank with the minimum water volume ensures that sufficient water is available to maintain the RCS at HOT STANDBY conditions for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months with steam discharge to the atmosphere concurrent with total loss of ofEsite power.

The contained water volume limit includes an allowance for water not xasable because of tank discharge line location or other physical characteristics.

SALEM - UNIrT 2 B 3/4 7-2 Amendment No.

225

PLANT SYSTEMS BASES 3/4.7.11 'FUEL STORAGE POOL BORON CONCENTRATION (continued)

The Required Actions are modified indicating that LCO 3.0.3 and LCO 3.0.; -4@

does not apply.

Storage of fuel assemblies and the boron concentration in the spent fuel storage pool are independent of reactor operation.

Therefore TS 3/4 3.7.21 and TS3/ 4 3.7.12 include the exception to LCO 3.0.3 andI LOC 3.0.4 to preclude an inappropriate reactor shutdown aen-larify that LCO 3.0.1 4doe: not fimpose modec eihangc--!Pcotr~ict!onc fet thoese iWhen the concentration of boror in the fuel storage pool is less than required, immediate action must be taken to preclude the occurrence of an accident or to mitigate the consequences of an accident in progress.

This is most efficiently achieved by immediately suspending the movement of fuel assemblies.

The concentration of boron is restored simultaneously with suspending movement of fuel assemblies.

Alternatively, beginning a verification of the fuel storage pool fuel locations, to ensure proper locations of the fuel, can be performed.

However, prior to resuming movement of fuel assemblies, the concentration of boron must be restored.

This does not preclude movement of a fuel assembly to a safe position.

If the LCO is not met while moving fuel assemblies in the spent fuel pool while in MODE 5 or 6, LCO 3.0.3 would not be applicable.

If moving fuel assemblies in the spent fuel pool while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation.

Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown or ^ im6s mo ohan;e This SR verifies that the concentration of boron in the fuel storage pool is within the required limit.

As long as this SR is met, the analyzed accidents are fully addressed.

The 7 day Frequency is appropriate because no major replenishment of pool water is expected to take place over such a short period of time.

Salem - Unit 2 B 3/4 7-11 Amendment No. 244

PLANT SYSTEMS I

BASES 3/4.7.12 IUEL ASSEMBLY STORAGE IN THE SPENT FUEL POOL (CONTINUED)

The restrictions on the placement of fuel assemblies within the spent fuel pool in accordance with TS 3/4.7.12, in the accompanying LCO, ensures the keff of the spent fuel storage pool will always remain < 0.95, assuming the pool to be flooded with unborated water.

This LCO applies whenever any fuel assembly is stored in Region 1 or Region 2 of the fuel s:orage pool.

The Required Actions are modified indicating that LCO 3.0.3 &nd LCO 3.0.1 does not apply.

Storage of fuel assemblies and the boron concentration in the spent fuel storage pool are independent of reactor operation. Therefore TS 3/4.3.7.11 and TS 3/4.3.7.12 include the exception to LCO 3.0.3 and LC 3.0.1 to preclude an inappropriate reactor shutdown an-zlarify that LCO 9.0.1 does not impose mode mange

trtibe fol those :cfi-

nz. When the configuration of fuel assemblies stored in Region 1 or Region 2 of the spent fuel storage pool is not in accordance with TS 3/4.7.12, the immediate action is to initiate action to make the necessary fuel assembly movement(s) to bring the configuration into compliance with TS 3/4.7.12.

If unable 1:o move fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not be applicable.. If unable to move fuel assemblies while in MODE 1, 2, 3, or 4, the action is independent of reactor operation.

Therefore, inability to move fuel assemblies is not sufficnent reason to require a reactor shutdown io mode chang:

The SR verifies by administrative means that the initial enrichment and burnup of the fuel assembly is in accordance with TS 3/4.7.12 in the accompanying LCO.

Salem

- Unit 2 B 3/4 7-13 Amendment No. 244

3/4.8 ELECTRICAL POWER SYSTEMS BASES 3/4.8.1 and 3/4.8.2 A.C. SOURCES AND ONSITE POWER DISTRIBUTION SYSTEMS The CPERABILITY of the A.C. and D.C power sources and associated distribution systems during operation ensures that sufficient power will be available to supply the safety related equipment required for 1) the safe shutdown of the facility, and

2) the mitigation and control of accident conditions within the facility.

The minimum specified independent and redundant A.C. and D.C. power sources and distribution systems satisfy the requirements of General Design Criterion 17 of Appendix "A" to 10 CFR Part 50.

Insert 7B H

lIThis should be inserted on next page.

l The ACTION requirements specified for the levels of degradation of the poser sources provide restriction upon continued facility operation commensurate with the level of degradation.

The OPERABILITY of the power sources are consistent with the initial condition assumptions of the accident analyses and are based upon maintaining at least too independent sets of onsite A.C. and D.C. power sources and associated distribution systems OPERABLE during accident conditions coincident with an assumed loss of offsite power and single failure of one onsite A.C. source.

When a system or component is determined to be inoperable solely because its emergency power source is inoperable, or solely because its normal power source is inoperable, it may still be considered OPERABLE, provided the appropriate Actions of 3.8.1.1.a.2, b.2 or d.2 are satisfied.

Action 3.8.1.1.a.2, which only applies if the train cannot be powered fron an offsite source, is intended to provide assurance that an event coincident with a single failure of the associated DG will not result in a complete loss of safety function o:f critical redundant required systems.

Failure of a single offsite circuit will generally not, by itself, cause any equipment to lose normal AC power.

Action 3.8.1.1.b.2 is intended to provide assurance that a loss of offsite power, during the period that a DG is inoperable, does not result in a complete loss of safety function of criticaL systems. Action 3.8.1.1.d.2, which applies when two offsite circuits are inoperable, is intended to provide assurance that an event with a coincident single failure wi-l not result in a complete loss of redundant required safety functions.

These systems are powered from the redundant AC electrical power train. This includes motor driven auxiliary feedwater pumps.

Single train systems, such as turbine driven auxiliary feedwater pumps, may not be included. Redundant required system or component failures consist of inoperable equipment associated with a -:rain, redundant to the train that has an inoperable DG or offsite power.

The completion time for these actions is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This completion time also allows for an exception to the normal "time zero" for beginning the allowed outage time clock, starting only on discovery that both:

a. One train has no offsite power supplying its loads, one DG is inoperable or two required offsite circuits are inoperable; and

b. A required system or component on the other train is inoperable.

If at any time during these conditions a redundant required system or component subsequently becomes inoperable, this completion time begins to be tracked.

Discovering no offsite power to one train of the onsite Class lE Electrical Power Distribution System, or one required DG inoperable, coincident with one or more inoperable required support or supported systems SALEM -

UNIT 2 B 3/4 8-1 Amendment No.234

v t e Letter Sequence Request
TAC:MD1426, Increase Flexibility in Mode Restraints (Approved, Closed)
Initiation Request Acceptance... Administration Questions Answers Results Approval Other: LR-N07-0103, Units 1 & 2, Correction to Technical Specification Pages/Amendment 276 and 258, ML063040648, ML071220291
MONTHYEAR2006-04-25 [Table View]

LR-N06-0120, Request for Change to Technical Specifications Regarding Mode Change Limitations Using the Consolidated Line Item Improvement Process (CLIIP) Salem Units 1 & 2

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LR-N06-0120, Request for Change to Technical Specifications Regarding Mode Change Limitations Using the Consolidated Line Item Improvement Process (CLIIP) Salem Units 1 & 2

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