Text

Supplement to Application to Revise Technical Specifications to Adopt TSTF-542, Reactor Pressure Vessel Water Inventory Control
	ML17319A297
Person / Time
Site:	Clinton
Issue date:	11/15/2017
From:	Simpson P; Exelon Generation Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	CAC MF9666, RS-17-145
	Download: ML17319A297 (161)
	v • d • e

4300 Winfield Road Warrenville, IL 60555 630 657 2000 Office RS-17-145 10 CFR 50.90 November 15, 2017 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001 Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 NRC Docket No. 50-461

Subject:

Supplement to Clinton Power Station, Unit 1 Application to Revise Technical Specifications to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control"

References:

(1)

Letter from P. R. Simpson (Exelon Generation Company, LLC (EGC)) to NRC, "Application to Revise Technical Specifications to Adopt TSTF-542,

'Reactor Pressure Vessel Water Inventory Control,'" dated April 27, 2017 (2)

Email from J. Rankin (NRC) to M. A. Mathews (EGC), "Clinton Power Station - Request for Additional Information Regarding License Amendment Request Related to Reactor Pressure Vessel Water Inventory Control (CAC No. MF9666)," dated October 3, 2017 In Reference 1, Exelon Generation Company, LLC (EGC) submitted a request for an amendment to the Technical Specifications (TS) for Clinton Power Station (CPS), Unit 1.

In Reference 2, the NRC determined that additional information was required to complete its evaluation of the Reference 1 request. The requested information, along with one additional variation from TSTF-542 related to the manual operation of a required emergency core cooling subsystem is provided in the attachments to this letter.

Additionally, on May 26, 2017, the NRC issued Operating License Amendment No. 212 for CPS, Unit 1. This amendment allows for the adoption of TSTF-545, "TS Inservice Testing Program Removal and Clarify Surveillance Requirement Usage Rule Application to Section 5.5 Testing." Attachment 2 to this letter provides revised markups of the CPS, Unit 1 TS to address issues identified in Reference 2, the adoption of TSTF-545, and the additional variation discussed above. These markups supersede those provided in Reference 1, Attachment 2 in their entirety. Attachment 3 provides the accompanying revised TS pages associated with the modifications shown in Attachment 2 as discussed above. Likewise, these pages supersede those provided in Reference 1, Attachment 3. Attachment 4 provides a markup of the TS Bases pages affected by the additional variation discussed above for information only.

November 15, 2017 U.S. Nuclear Regulatory Commission Page 2 EGC has reviewed the information supporting a finding of no significant hazards consideration, and the environmental consideration, that were previously provided to the NRC ln Reference 1.

The additional information provided in this submittal does not affect the bases for concluding that the proposed license amendment does not involve a significant hazards consideration. In addition, the information provided in this submittal does not affect the bases for concluding that neither an environmental impact statement nor an environmental assessment needs to be prepared in connection with the proposed amendment.

EGC is notifying the State of Illinois of this supplement to a previous application for a change to the TS by sending a copy of this letter and its attachment to the designated State Official in accordance with 10 CFR 50.91, "Notice for public comment; State consultation," paragraph (b).

Based on the NRC's review timeline associated with the Reference 1 request and recent discussions with the Office of Nuclear Reactor Regulation Project Manager for CPS, Unit 1, Jennivine Rankin, EGG proposes a revision to the implementation period for the Reference 1 request. EGC proposes that once the Reference 1 request is approved, the amendment shall be implemented for CPS, Unit 1 prior to entering Mode 4 during the next refueling outage, C1R18, currently planned for April 2018.

There are no regulatory commitments contained within this letter.

Should you have any questions concerning this letter, please contact Mr. Mitchel A. Mathews at (630) 657-2819.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the 15th day of November 2017.

RfmR Patrick R. Simpson Manager-Licensing Exelon Generation Company, LLC Attachments:

1.

Supplemental Information Related to Request to Adopt TSTF-542, "Reactor Pressure Vessel (RPV) Water Inventory Control," for Clinton Power Station, Unit 1

2.

Proposed Technical Specifications Changes (Mark-Up)

3.

Revised Technical Specifications Pages

4.

Technical Specifications Bases Pages Affected by the Additional Variation (Mark-Up}

cc:

NRG Regional Administrator, Region Ill NRC Senior Resident Inspector-Clinton Power Station Illinois Emergency Management Agency - Division of Nuclear Safety

Clinton Power Station, Unit 1 Supplement to Clinton Power Station, Unit 1 Application to Revise Technical Specifications to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control" ATTACHMENT 1 -

Supplemental Information Related to Request to Adopt TSTF-542, "Reactor Pressure Vessel (RPV) Water Inventory Control," for Clinton Power Station, Unit 1

SUPPLEMENTAL INFORMATION RELATED TO REQUEST TO ADOPT TSTF-542, "REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL," FOR CLINTON POWER STATION, UNIT 1 Page 1 of 4 REQUEST FOR ADDITIONAL INFORMATION EXELON GENERATION COMPANY, LLC CLINTON POWER STATION, UNIT 1 LICENSE AMENDMENT REQUEST RELATED TO REACTOR PRESSURE VESSEL WATER INVENTORY CONTROL DOCKET NO. 50-461 By application dated May 1, 2017 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML17121A517), Exelon Generation Company, LLC (the licensee),

requested a change to the technical specifications (TSs) for Clinton Power Station, Unit 1 (CPS). The proposed change adopts technical specifications task force (TSTF) traveler TSTF-542, "Reactor Pressure Vessel Water Inventory Control," Revision 2 (ADAMS Accession No. ML16074A448). Specifically, the proposed changes would replace the existing requirements in the TSs related to operation with a potential for draining the reactor vessels (OPDRVs) with revised TSs providing an alternative for reactor pressure vessel water inventory control (RPV WIC). These alternative requirements would protect Safety Limit 2.1.1.3, which requires RPV water level to be greater than the top of active fuel.

TSTF-542, Revision 2, was approved by the U.S. Nuclear Regulatory Commission (NRC) on December 20, 2016 (ADAMS Accession No. ML16343B008).

Based on its review of the amendment request, the NRC staff has determined that additional information is required to complete the review.

RAI 1

The staff has identified an apparent discrepancy in Attachment 2, page 3.5-11 of the license amendment request (LAR). Specifically, the current TSs (i.e., current TS surveillance requirements 3.5.2.5 and 3.5.2.6) contain text not shown in the proposed markup as being deleted.

For clarity, please correct the proposed TS markup, as appropriate Exelon Generation Company, LLC (EGC) Response The markups for SR 3.5.2.5 and SR 3.5.2.6 are incorporated in the revised TS markups included in Attachment 2 on Page 3.5-10.

SUPPLEMENTAL INFORMATION RELATED TO REQUEST TO ADOPT TSTF-542, "REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL," FOR CLINTON POWER STATION, UNIT 1 Page 2 of 4

RAI 2

TSTF-542, Revision 2 changes the title of TS 3.5.2 from "ECCS - Shutdown" to "RPV Water Inventory Control." Current TS 3.8.2, "AC Sources - Shutdown," TS 3.8.5, "DC Sources -

Shutdown," and TS 3.8.8, "Inverters - Shutdown," reference TS 3.5.2, "ECCS-Shutdown."

There was not any revised TS pages submitted in the LAR to reflect the changes to these sections.

Please provide revised and markup TS pages for these sections, as appropriate.

EGC Response The requested changes are incorporated in the revised markups included in Attachment 2 on Pages 3.8-16, 3.8-27, and 3.8-36.

RAl 3

, pages 3.3-54 through 3.3-59 of the LAR provides a markup of Table 3.3.6.1-1, "Primary Containment and Drywell Isolation Instrumentation." Due to the deletion of Footnote (c), which states, "During operations with a potential for draining the reactor vessel," the following instrumentation were affected.

Function 2 (Primary Containment and drywell isolation), Item a, "Reactor Vessel Water Level Low Low, Level 2" Function 2, Item g, "Containment Building Fuel Transfer Pool Ventilation Plenum Radiation High" Function 2, Item h, "Containment Building Exhaust Radiation High" Function 2, Item i, "Containment Building Continuous Containment Purge (CCP) Exhaust Radiation High" Function 2, Item j, "Reactor Vessel Water Level Low Low Low, Level 1" Function 2, Item l, "Manual Initiation" Function 4 (reactor water cleanup system isolation), Item f, "Reactor Vessel Level Low Low, Level 2" Function 4, Item h, "Manual Initiation" Table 3.3.6.1-1, "Primary Containment Isolation Instrumentation" in TSTF-542, Revision 2 modifies Function 2.g, "Containment and Drywell Ventilation Exhaust Radiation High," in relation to the removal of Footnote (b) which states, "or operations with a potential for draining the reactor vessel."

Compared to the TSTF-542, Revision 2, CPS proposed to delete additional instrumentation (related to the Applicability during Modes 4 and 5 or OPDRVs) from its TSs. Please provide a technical variation to describe the deviations between the proposed CPS TSs and TSTF 542, Revision 2.

SUPPLEMENTAL INFORMATION RELATED TO REQUEST TO ADOPT TSTF-542, "REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL," FOR CLINTON POWER STATION, UNIT 1 Page 3 of 4 EGC Response All of these instrument functions serve to isolate Primary Containment penetrations that bypass Secondary Containment; therefore, they function to isolate a portion of the Secondary Containment boundary for Clinton Power Station (CPS), Unit 1. Under the proposed Technical Specification (TS) 3.5.2 "Reactor Pressure Vessel Water Inventory Control," requirements, Secondary Containment must be isolated or capable of being isolated in less than the Drain Time when the Drain Time is less than 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , but automatic Secondary Containment isolation is not required. A draining event is a slow evolution when compared to a design basis loss of coolant accident that is assumed to occur at full power, and thus there is adequate time to take manual actions (i.e., hours versus minutes). The proposed TS 3.5.2, Action E, prohibits plant conditions that could result in Drain Times less than one hour. Therefore, there is sufficient time for the licensed operators to take manual action to stop the draining event, or to establish the Secondary Containment boundary and to isolate the Secondary Containment penetration flow paths before Secondary Containment isolation would be required.

Consequently, there is no need for automatic initiation of Secondary Containment isolation to respond to an unexpected draining event. The Required Actions of proposed TS 3.5.2 will require Secondary Containment isolation, or verification that it can be manually isolated, when the Drain Time is less than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and no draining event has occurred. This provides a greater level of safety. Excluding these functions from Table 3.3.5.2-1 is addressed by the proposed Limiting Condition for Operation (LCO) 3.5.2, "RPV Water Inventory Control." Specifically, by LCO 3.5.2, Required Actions C.1 and D.2 which are: "Verify secondary containment boundary is capable of being established in less than the DRAIN TIME," and "Initiate action to establish secondary containment boundary," respectively. This approach is consistent with Section 3.4.1.3 of the Justification for TSTF-542, Revision 2.

Additional Proposed Variation for Instrumentation Functions:

EGC proposes to revise Table 3.3.5.2-1, "RPV Water Inventory Control Instrumentation," to reflect the CPS, Unit 1 design. Specifically, Function 1, "Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS) Subsystems," Function 1.d, "Manual Initiation,"

Function 2, "LPCI B and LPCI C Subsystems," Function 2.c, "Manual Initiation," and Function 3, High Pressure Core Spray (HPCS) System, Function 3.a, "Reactor Vessel Water Level - High, Level 8," and Function 3.e, "Manual initiation," that appear in the BWR/6 Technical Specifications in TSTF-542 are no longer included in the CPS Technical Specifications as proposed. This corrects an issue in TSTF-542 associated with the BWR/5 and BWR/6 emergency core cooling system (ECCS) instrumentation requirements.

The purpose of the manual initiation functions is to allow manual actuation of the ECCS subsystems required by TS 3.5.2 to mitigate a draining event. Licensed operators in the Main Control Room have the capability to manually start the LPCI, LPCS, and HPCS pumps and to manually align valves to add water inventory, if needed. This can be accomplished without the "Manual Initiation" functions, and the "Reactor Vessel Water Level-High, Level 8" function associated with HPCS. If the water level is above Level 8, and HPCS is the required ECCS subsystem, the Level 8 function can be intentionally defeated to allow the HPCS injection valve to be opened, if needed to control inventory. All actions can be performed from the Main

SUPPLEMENTAL INFORMATION RELATED TO REQUEST TO ADOPT TSTF-542, "REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL," FOR CLINTON POWER STATION, UNIT 1 Page 4 of 4 Control Room and can be accomplished well within the one-hour minimum drain time limit specified in TS 3.5.2, Condition E.

The Reactor Vessel Water Level High, Level 8 signal (i.e., TSTF-542, Table 3.3.5.2-1, Function 3.a) prevents overfilling of the reactor vessel into the main steam lines by closing the HPCS injection valves when the water level is above the Level 8 setpoint. Therefore, if HPCS is the required ECCS subsystem and the water level is above Level 8, using the "Manual Initiation" Function 3.e will not result in inventory injection into the reactor vessel until the water level drops below the Level 8 setpoint. If the Level 8 function is retained in Table 3.3.5.2-1, the function would need to be rendered inoperable in order to inject water when the water level is above the Level 8 setpoint.

Consequently, Table 3.3.5.2-1, Functions 1.d, 2.c, 3.a, and 3.e, and TS 3.3.5.2, Condition E and associated Required Actions E.1, and E.2 as described in TSTF-542 are not needed to actuate the LPCI, LPCS, and HPCS subsystem components to mitigate a draining event, and are not included in the proposed Table 3.3.5.2-1 for CPS. The remaining functions and Conditions have been renumbered accordingly.

To address the changes associated with the proposed additional variation discussed above, EGC also proposes that Surveillance Requirement (SR) SR 3.5.2.8 be modified to verify that the CPS, Unit 1 required ECCS injection/spray subsystem can be manually operated from the Main Control Room in accordance with the Surveillance Frequency Control Program as shown in Figure 1 below. This will ensure that the required ECCS injection/spray subsystem is Operable and can be manually aligned to provide RPV inventory makeup, if required to do so, without delay.

Figure 1: Proposed SR 3.5.2.8

Clinton Power Station, Unit 1 Supplement to Clinton Power Station, Unit 1 Application to Revise Technical Specifications to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control" ATTACHMENT 2 PROPOSED TECHNICAL SPECIFICATIONS CHANGES (MARK-UP)

TOC Page ii TOC Page iii TOC Page iv 1.0-1 1.0-2 1.0-3 1.0-4 1.0-5 3.3-32 3.3-33 3.3-35 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-43a 3.3-43b 3.3-43c 3.3-43d 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.3-56 3.3-57 3.3-58 3.3-59 3.3-60 3.3-64 3.3-77 3.5-1 3.5-6 3.5-7 3.5-8 3.5-9 3.5-10 3.5-11 3.5-12 3.6-3 3.6-7 3.6-9 3.6-14 3.6-43 3.6-44 3.6-47 3.6-49 3.6-51 3.6-52 3.6-53 3.7-4 3.7-5 3.7-6 3.7-8 3.7-9 3.7-10 3.8-16 3.8-17 3.8-18 3.8-27 3.8-28 3.8-36 3.8-37 3.8-43

TABLE OF CONTENTS CLINTON Revision No. 2-13 iii B 3.3 INSTRUMENTATION (continued)

B 3.3.3.2 Remote Shutdown System....................................B 3.3-60 B 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation...........................................B 3.3-65 B 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation........B 3.3-76 B 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation......B 3.3-85 B 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory ControlReactor Core Isolation Cooling (RCIC) System Instrumentation...................................... B 3.3-123122a B 3.3.5.23 Reactor Core Isolation Cooling (RCIC) System Instrumentation...................................... B 3.3-123 B 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation.........................B 3.3-135 B 3.3.6.2 Secondary Containment Isolation Instrumentation...........B 3.3-174 B 3.3.6.3 Residual Heat Removal (RHR) Containment Spray System Instrumentation...........................................B 3.3-186 B 3.3.6.4 Suppression Pool Makeup (SPMU) System Instrumentation.....B 3.3-197 B 3.3.6.5 Relief and Low-Low Set (LLS) Instrumentation..............B 3.3-208 B 3.3.7.1 Control Room Ventilation (CRV) System Instrumentation.....B 3.3-215 B 3.3.8.1 Loss of Power (LOP) Instrumentation.......................B 3.3-222 B 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring.....................................B 3.3-230 3.4 REACTOR COOLANT SYSTEM (RCS)..................................3.4-1 3.4.1 Recirculation Loops Operating.............................3.4-1 3.4.2 Flow Control Valves (FCVs)................................3.4-6 3.4.3 Jet Pumps.................................................3.4-8 3.4.4 Safety/Relief Valves (S/RVs)..............................3.4-10 3.4.5 RCS Operational LEAKAGE...................................3.4-12 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage................3.4-14 3.4.7 RCS Leakage Detection Instrumentation.....................3.4-17 3.4.8 RCS Specific Activity.....................................3.4-20 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown......................................3.4-22 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown.....................................3.4-25 3.4.11 RCS Pressure and Temperature (P/T) Limits.................3.4-27 3.4.12 Reactor Steam Dome Pressure...............................3.4-33 B 3.4 REACTOR COOLANT SYSTEM (RCS)..................................B 3.4-1 B 3.4.1 Recirculation Loops Operating.............................B 3.4-1 B 3.4.2 Flow Control Valves (FCVs)................................B 3.4-9 (continued)

TABLE OF CONTENTS CLINTON Revision No. 14-2 iv B 3.4 REACTOR COOLANT SYSTEM (RCS) (continued)

B 3.4.3 Jet Pumps.................................................B 3.4-13 B 3.4.4 Safety/Relief Valves (S/RVs)..............................B 3.4-17 B 3.4.5 RCS Operational LEAKAGE...................................B 3.4-23 B 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage................B 3.4-28 B 3.4.7 RCS Leakage Detection Instrumentation.....................B 3.4-33 B 3.4.8 RCS Specific Activity.....................................B 3.4-39 B 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown..................................B 3.4-43 B 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown.................................B 3.4-48 B 3.4.11 RCS Pressure and Temperature (P/T) Limits.................B 3.4-53 B 3.4.12 Reactor Steam Dome Pressure...............................B 3.4-63 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM..............................3.5-1 3.5.1 ECCS - Operating...........................................3.5-1 3.5.2 RPV Water Inventory ControlECCS - Shutdown.................3.5-6 3.5.3 RCIC System...............................................3.5-1011 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM.........................B 3.5-1 B 3.5.1 ECCS - Operating...........................................B 3.5-1 B 3.5.2 ECCS - ShutdownRPV Water Inventory Control.................B 3.5-1517 B 3.5.3 RCIC System...............................................B 3.5-2127 3.6 CONTAINMENT SYSTEMS...........................................3.6-1 3.6.1.1 Primary Containment.......................................3.6-1 3.6.1.2 Primary Containment Air Locks.............................3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs)..............3.6-9 3.6.1.4 Primary Containment Pressure..............................3.6-20 3.6.1.5 Primary Containment Air Temperature.......................3.6-21 3.6.1.6 Low-Low Set (LLS) Valves..................................3.6-22 3.6.1.7 Residual Heat Removal (RHR) Containment Spray System......3.6-24 3.6.1.8 Deleted...................................................3.6-26 3.6.1.9 Feedwater Leakage Control System (FWLCS)..................3.6-27a 3.6.2.1 Suppression Pool Average Temperature......................3.6-28 3.6.2.2 Suppression Pool Water Level..............................3.6-31 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling......3.6-32 3.6.2.4 Suppression Pool Makeup (SPMU) System.....................3.6-34 3.6.3.1 Deleted.................................................3.6-36 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters.........3.6-38 (continued)

Definitions 1.1 CLINTON 1.0-1 Amendment No. 105 1.0 USE AND APPLICATION 1.1 Definitions

NOTE-------------------------------------

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

AVERAGE PLANAR LINEAR The APLHGR shall be applicable to a specific HEAT GENERATION RATE planar height and is equal to the sum of the (APLHGR)

LHGRs for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle at the height.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY and the CHANNEL FUNCTIONAL TEST.

Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps.

(continued)

Definitions 1.1 CLINTON 1.0-2 Amendment No. 105 1.1 Definitions (continued)

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel,sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS:

a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement);

and

b. Control rod movement, provided there are no fuel assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT I-131 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries/gram) that alone would produce the same inhalation CEDE dose as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The inhalation CEDE dose conversion factors used for this calculation shall be those listed in Table 2.1 of Federal Guidance Report 11, Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion, ORNL, 1989.

DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a.

The water inventory above the TAF is divided by the limiting drain rate;

b.

The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g.,

seismic event, loss of normal power, single human error), for all (continued)

Definitions 1.1 CLINTON 1.0-3 Amendment No. 105 Definitions DRAIN TIME penetration flow paths below the TAF except:

(continued)

1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.

c. The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;

d. No additional draining events occur; and

e. Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

EMERGENCY CORE COOLING The ECCS RESPONSE TIME shall be that time interval SYSTEM (ECCS) RESPONSE from when the monitored parameter exceeds its ECCS TIME initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

(continued)

Definitions 1.1 CLINTON 1.0-4 Amendment No. 105 1.1 Definitions (continued)

END OF CYCLE The EOC-RPT SYSTEM RESPONSE TIME shall be that RECIRCULATION PUMP TRIP time interval from initial movement of the (EOC-RPT) SYSTEM RESPONSE associated turbine stop valve or turbine TIME control valve to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

ISOLATION SYSTEM The ISOLATION SYSTEM RESPONSE TIME shall be that RESPONSE TIME time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves travel to their required positions. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE;

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE;

d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

(continued)

Definitions 1.1 CLINTON 1.0-5 Amendment No. 95 128 1.1 Definitions (continued)

LINEAR HEAT GENERATION The LHGR shall be the heat generation rate per RATE (LHGR) unit length of fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length.

LOGIC SYSTEM FUNCTIONAL A LOGIC SYSTEM FUNCTIONAL TEST shall be a test TEST of all logic components required for OPERABILITY of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

MINIMUM CRITICAL POWER The MCPR shall be the smallest critical power RATIO (MCPR) ratio (CPR) that exists in the core for each class of fuel. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

MODE A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE OPERABILITY A system, subsystem, division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP) rate to the reactor coolant of 3473 MWt.

REACTOR PROTECTION The RPS RESPONSE TIME shall be that time interval SYSTEM (RPS) RESPONSE from when the monitored parameter exceeds its RPS TIME trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

(continued)

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-32 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

B.1

NOTES---------

1. Only applicable in MODES 1, 2, and 3.

2. Only applicable for Functions 1.a, 1.b, 2.a, and 2.b.

Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

AND 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for feature(s) in both divisions B.2

NOTES---------

1. Only applicable in MODES 1, 2, and 3.

2. Only applicable for Functions 3.a and 3.b.

Declare High Pressure Core Spray (HPCS)

System inoperable.

AND B.3 Place channel in trip.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of HPCS initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-33 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

C.1

NOTES--------

1. Only applicable in MODES 1, 2, and 3.

2. Only applicable for Functions 1.c, 1.d, 2.c, and 2.d.

Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

AND 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for feature(s) in both divisions C.2 Restore channel to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-35 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

E.1

NOTES---------

1. Only applicable in MODES 1, 2, and 3.

2. Only applicable for Functions 1.e, 1.f, and 2.e.

Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

AND E.2 Restore channel to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for feature(s) in both divisions 7 days (continued)

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-39 Amendment No. 169 Table 3.3.5.1-1 (page 1 of 5)

Emergency Core Cooling System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)

Subsystems

a. Reactor Vessel Water Level-Low Low Low, Level 1 1,2,3, 4(a),5(a) 2(ba)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.5 SR 3.3.5.1.6(ec)

-148.1 inches

b. Drywell Pressure-High 1,2,3 2(ba)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 1.88 psig

c. LPCI Pump A Start-Time Delay Logic Card 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 4.5 seconds and 5.5 seconds

d. Reactor Vessel Pressure-Low (Injection Permissive) 1,2,3 4

C SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 454 psig and 494 psig 4(a),5(a) 4 B

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(e)

SR 3.3.5.1.4(e)

SR 3.3.5.1.5 454 psig and 494 psig

e. LPCS Pump Discharge Flow-Low (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 750 gpm

f. LPCI Pump A Discharge Flow-Low (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 900 gpm

g. Manual Initiation 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.5 NA (continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(ba) Also required to initiate the associated diesel generator.

(ec) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined As-Found Tolerance band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value within the As-Left Tolerance of the Actual Trip Setpoint; otherwise, the channel shall be declared inoperable.

3. The Nominal Trip Setpoint and the methodology used to determine the Nominal Trip Setpoint, the predefined As-Found Tolerance and As-Left Tolerance bands shall be specified in the ORM.

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-40 Amendment No. 169 Table 3.3.5.1-1 (page 2 of 5)

Emergency Core Cooling System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel Water Level-Low Low Low, Level 1 1,2,3, 4(a),5(a) 2(ba)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.5 SR 3.3.5.1.6(ec)

-148.1 inches

b. Drywell Pressure-High 1,2,3 2(ba)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 1.88 psig

c. LPCI Pump B Start-Time Delay Logic Card 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 4.5 seconds and 5.5 seconds

d. Reactor Vessel Pressure-Low (Injection Permissive) 1,2,3 4

C SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 454 psig and 494 psig 4(a),5(a) 4 B

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(e)

SR 3.3.5.1.4(e)

SR 3.3.5.1.5 454 psig and 494 psig

e. LPCI Pump B and LPCI Pump C Discharge Flow-Low (Bypass) 1,2,3, 4(a),5(a) 1 per pump E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 900 gpm

f. Manual Initiation 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.5 NA (continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(ba) Also required to initiate the associated diesel generator.

(ec) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined As-Found Tolerance band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value within the As-Left Tolerance of the Actual Trip Setpoint; otherwise, the channel shall be declared inoperable.

3. The Nominal Trip Setpoint and the methodology used to determine the Nominal Trip Setpoint, the predefined As-Found Tolerance and As-Left Tolerance bands shall be specified in the ORM.

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-41 Amendment No. 169 Table 3.3.5.1-1 (page 3 of 5)

Emergency Core Cooling System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel Water Level-Low Low, Level 2 1,2,3, 4(a),5(a) 4(ba)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.5 SR 3.3.5.1.6(ec)

-48.1 inches

b. Drywell Pressure - High 1,2,3 4(ba)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 1.88 psig

c. Reactor Vessel Water Level-High, Level 8 1,2,3, 4(a),5(a) 2 C

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.5 SR 3.3.5.1.6(ec) 54.6 inches

d. RCIC Storage Tank Level-Low 1,2,3, 4(c),5(c) 2 D

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 3.0 inches

e. Suppression Pool Water Level-High 1,2,3 2

D SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 11 inches

f. HPCS Pump Discharge Pressure-High (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 120 psig

g. HPCS System Flow Rate-Low (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 500 gpm

h. Manual Initiation 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.5 NA (continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(ba) Also required to initiate the associated diesel generator.

(c) When HPCS is OPERABLE for compliance with LCO 3.5.2, "ECCS-Shutdown," and aligned to the RCIC storage tank while tank water level is not within the limits of SR 3.5.2.2.

(ec) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined As-Found Tolerance band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value within the As-Left Tolerance of the Actual Trip Setpoint; otherwise, the channel shall be declared inoperable.

3. The Nominal Trip Setpoint and the methodology used to determine the Nominal Trip Setpoint, the predefined As-Found Tolerance and As-Left Tolerance bands shall be specified in the ORM.

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-42 Amendment No. 169 Table 3.3.5.1-1 (page 4 of 5)

Emergency Core Cooling System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

4. Automatic Depressurization System (ADS) Trip System 1 (Logic A and E)

a. Reactor Vessel Water Level-Low Low Low, Level 1 1,2(db),3(db) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.5 SR 3.3.5.1.6(ec)

-148.1 inches

b. Drywell Pressure-High 1,2(db),3(db) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 1.88 psig

c. ADS Initiation Timer 1,2(db),3(db) 1 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 117 seconds

d. Reactor Vessel Water Level-Low, Level 3 (Confirmatory) 1,2(db),3(db) 1 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 8.3 inches

e. LPCS Pump Discharge Pressure-High 1,2(db),3(db) 2 G

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 125 psig and

< 176.3 psig

f. LPCI Pump A Discharge Pressure-High 1,2(db),3(db) 2 G

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 115 psig and

< 135 psig

g. ADS Drywell Pressure Bypass Timer 1,2(db),3(db) 2 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 6.5 minutes

h. Manual Initiation 1,2(db),3(db) 2 G

SR 3.3.5.1.5 NA (continued)

(d) (b) With reactor steam dome pressure > 150 psig.

(ec) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined As-Found Tolerance band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value within the As-Left Tolerance of the Actual Trip Setpoint; otherwise, the channel shall be declared inoperable.

3. The Nominal Trip Setpoint and the methodology used to determine the Nominal Trip Setpoint, the predefined As-Found Tolerance and As-Left Tolerance bands shall be specified in the ORM.

ECCS Instrumentation 3.3.5.1 CLINTON 3.3-43 Amendment No. 169 Table 3.3.5.1-1 (page 5 of 5)

Emergency Core Cooling System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

5. ADS Trip System 2 (Logic B and F)

a. Reactor Vessel Water Level-Low Low Low, Level 1 1,2(db),3(db) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.5 SR 3.3.5.1.6(ec)

-148.1 inches

b. Drywell Pressure-High 1,2(db),3(db) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 1.88 psig

c. ADS Initiation Timer 1,2(db),3(db) 1 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 117 seconds

d. Reactor Vessel Water Level-Low, Level 3 (Confirmatory) 1,2(db),3(db) 1 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.4 SR 3.3.5.1.5 8.3 inches

e. LPCI Pumps B & C Discharge Pressure-High 1,2(db),3(db) 2 per pump G

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3(ec)

SR 3.3.5.1.4(ec)

SR 3.3.5.1.5 115 psig and 135 psig

f. ADS Drywell Pressure Bypass Timer 1,2(db),3(db) 2 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 6.5 minutes

g. Manual Initiation 1,2(db),3(db) 2 G

SR 3.3.5.1.5 NA (db) With reactor steam dome pressure > 150 psig.

(ec) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined As-Found Tolerance band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value within the As-Left Tolerance of the Actual Trip Setpoint; otherwise, the channel shall be declared inoperable.

3. The Nominal Trip Setpoint and the methodology used to determine the Nominal Trip Setpoint, the predefined As-Found Tolerance and As-Left Tolerance bands shall be specified in the ORM.

RPV Water Inventory Control Instrumentation 3.3.5.2 CLINTON 3.3-43a Amendment No. 95 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.2-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels inoperable.

A.1 Enter the Condition referenced in Table 3.3.5.2-1 for the channel.

Immediately B. As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

B.1 Declare associated penetration flow path(s) incapable of automatic isolation.

AND B.2 Calculate DRAIN TIME.

Immediately Immediately C. As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

C.1 Place channel in trip.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (continued)

RPV Water Inventory Control Instrumentation 3.3.5.2 CLINTON 3.3-43b Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

D.1 Declare HPCS system inoperable.

OR D.2 Align the HPCS pump suction to the suppression pool.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 1 hour E. As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

E.1 Restore channel to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months F. Required Action and associated Completion Time of Condition C, D, or E not met.

F.1 Declare associated ECCS injection/spray subsystem inoperable.

Immediately

RPV Water Inventory Control Instrumentation 3.3.5.2 CLINTON 3.3-43c Amendment No. 9 5 SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 Perform LOGIC SYSTEM FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program

RPV Water Inventory Control Instrumentation 3.3.5.2 CLINTON 3.3-43d Amendment No. 95 Table 3.3.5.2-1 (page 1 of 2)

RPV Water Inventory Control Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)

Subsystems

a.

Reactor Vessel Pressure -

Low (Injection Permissive) 4,5 4(a)

C SR 3.3.5.2.1 SR 3.3.5.2.2 494 psig

b. LPCS Pump Discharge Flow -

Low (Bypass) 4,5 1 per pump(a)

E SR 3.3.5.2.1 SR 3.3.5.2.2 750 gpm

c. LPCI Pump A Discharge Flow -

Low (Bypass) 4,5 1 per pump(a)

E SR 3.3.5.2.1 SR 3.3.5.2.2 900 gpm

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel Pressure - Low (Injection Permissive) 4,5 4(a)

C SR 3.3.5.2.1 SR 3.3.5.2.2 494 psig

b. LPCI Pump B and LPCI Pump C Discharge Flow -

Low (Bypass) 4,5 1 per pump(a)

E SR 3.3.5.2.1 SR 3.3.5.2.2 900 gpm (continued)

(a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "RPV Water Inventory Control."

RPV Water Inventory Control Instrumentation 3.3.5.2 CLINTON 3.3-44 Amendment No.

Table 3.3.5.2-1 (page 2 of 2)

RPV Water Inventory Control Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

3. High Pressure Core Spray (HPCS) System

a. RCIC Storage Tank Level - Low 4(b), 5(b) 2(a)

D SR 3.3.5.2.1 SR 3.3.5.2.2 3.0 inches

b. HPCS Pump Discharge Pressure - High (Bypass) 4, 5 1(a)

E SR 3.3.5.2.1 SR 3.3.5.2.2 120 psig

c. HPCS System Flow Rate - Low (Bypass) 4, 5 1(a)

E SR 3.3.5.2.1 SR 3.3.5.2.2 500 gpm

4. RHR System Isolation

a. Reactor Vessel Water Level -

Low, Level 3 (c) 2 in one trip system B

SR 3.3.5.2.1 SR 3.3.5.2.2 8.3 inches

5. Reactor Water Cleanup (RWCU) System Isolation

a. Reactor Vessel Water Level - Low Low, Level 2 (c) 2 in one trip system B

SR 3.3.5.2.1 SR 3.3.5.2.2

-48.1 inches (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "RPV Water Inventory Control."

(b) When HPCS is OPERABLE for compliance with LCO 3.5.2, "RPV Water Inventory Control," and aligned to the RCIC storage tank while tank water level is not within the limits of SR 3.5.2.3.

(c) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME.

RCIC System Instrumentation 3.3.5.32 CLINTON 3.3-45 Amendment No. 95 3.3 INSTRUMENTATION 3.3.5.2 3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.23 The RCIC System instrumentation for each Function in Table 3.3.5.23-1 shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

NOTE--------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more channels inoperable.

A.1 Enter the Condition referenced in Table 3.3.5.23-1 for the channel.

Immediately B.

As required by Required Action A.1 and referenced in Table 3.3.5.23-1.

B.1 Declare RCIC System inoperable.

AND B.2 Place channel in trip.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of RCIC initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C.

As required by Required Action A.1 and referenced in Table 3.3.5.23-1.

C.1 Restore channel to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

RCIC System Instrumentation 3.3.5.32 CLINTON 3.3-46 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

As required by Required Action A.1 and referenced in Table 3.3.5.23-1.

D.1

NOTE----------

Only applicable if RCIC pump suction is not aligned to the suppression pool.

Declare RCIC System inoperable.

AND D.2.1 Place channel in trip.

OR D.2.2 Align RCIC pump suction to the suppression pool.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of RCIC initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours E.

Required Action and associated Completion Time of Condition B, C, or D not met.

E.1 Declare RCIC System inoperable.

Immediately

RCIC System Instrumentation 3.3.5.32 CLINTON 3.3-47 Amendment No. 192 SURVEILLANCE REQUIREMENTS

NOTES-------------------------------------

1. Refer to Table 3.3.5.23-1 to determine which SRs apply for each RCIC Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 2 and 5; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.23.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.23.2 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.23.3 Calibrate the analog trip module.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.23.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.23.5 Perform LOGIC SYSTEM FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.23.6 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program

RCIC System Instrumentation 3.3.5.32 CLINTON 3.3-48 Amendment No. 169 Table 3.3.5.23-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation FUNCTION REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1. Reactor Vessel Water Level-Low Low, Level 2 4

B SR 3.3.5.23.1 SR 3.3.5.23.2 SR 3.3.5.23.3 SR 3.3.5.23.5 SR 3.3.5.23.6

-48.1 inches

2. Reactor Vessel Water Level-High, Level 8 2

C SR 3.3.5.23.1 SR 3.3.5.23.2 SR 3.3.5.23.3 SR 3.3.5.23.4 SR 3.3.5.23.5 52.6 inches

3. RCIC Storage Tank Level-Low 2

D SR 3.3.5.23.1 SR 3.3.5.23.2 SR 3.3.5.23.3 SR 3.3.5.23.4 SR 3.3.5.23.5 3.0 inches

4. Suppression Pool Water Level-High 2

D SR 3.3.5.23.1 SR 3.3.5.23.2 SR 3.3.5.23.3 SR 3.3.5.23.4 SR 3.3.5.23.5

-5 inches

5. Manual Initiation 1

C SR 3.3.5.23.5 NA

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-49 Amendment No. 95 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation LCO 3.3.6.1 The primary containment and drywell isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.6.1-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME

NOTE----------

Only applicable to Main Steam Line (MSL) isolation Functions.

A. One or more Functions with one channel inoperable.

A.1 Place one channel in affected Function in trip.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months

NOTE----------

Only applicable to MSL isolation Functions.

B.

One or more Functions with two channels inoperable.

B.1 Place one channel in affected Function in trip.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

NOTE----------

Only applicable to MSL isolation Functions.

C. One or more Functions with three or more channels inoperable.

C.1 Restore two channels in affected Function to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (continued)

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-50 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

NOTE----------

Not applicable to MSL isolation Functions.

D. One or more required channels inoperable.

D.1 Place channel in trip.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

NOTE---------

Not applicable to MSL isolation Functions.

E. One or more automatic Functions with isolation capability not maintained.

E.1 Restore isolation capability.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months F. Required Action and associated Completion Time of Condition A, B, C, D, or E not met.

F.1 Enter the Condition referenced in Table 3.3.6.1-1 for the channel.

Immediately G. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

G.1 Isolate associated MSL.

OR G.2.1 Be in MODE 3.

AND G.2.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

H.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months I. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

I.1 Isolate the affected penetration flow path(s).

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (continued)

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-51 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

J.1 Isolate the affected penetration flow path(s).

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months K. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

OR Required Action and associated Completion Time of Condition I or J not met.

K.1 Be in MODE 3.

AND K.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours L. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

L.1 Declare associated standby liquid control subsystem inoperable.

OR L.2 Isolate the Reactor Water Cleanup System.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 1 hour M. As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

M.1 Initiate action to restore channel to OPERABLE status.

OR M.2 Initiate action to isolate the Residual Heat Removal (RHR)

Shutdown Cooling System suction from the reactor vessel.

OR Immediately Immediately (continued)

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-52 Amendment No. 95 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME M.

(Continued)

M.3.1 Initiate action to restore secondary containment to OPERABLE status.

AND M.3.2 Initiate action to restore one standby gas treatment (SGT) subsystem to OPERABLE status.

AND M.3.3 Initiate action to restore isolation capability in each required secondary containment and secondary containment bypass penetration flow path not isolated.

AND M.3.4

NOTE-------

Entry and exit is permissible under administrative control.

Initiate action to close one door in the upper containment personnel air lock.

Immediately Immediately Immediately Immediately N.

As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

N.1 Isolate the affected penetration flow path(s).

OR N.2 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND N.2.2 Initiate action to suspend operations with a potential for draining the reactor vessel.

Immediately Immediately Immediately (continued)

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-53 Amendment No. 192 CONDITION REQUIRED ACTION COMPLETION TIME O.

As required by Required Action F.1 and referenced in Table 3.3.6.1-1.

O.1 Isolate the affected penetration flow path(s).

OR O.2 Initiate action to suspend operations with a potential for draining the reactor vessel.

Immediately Immediately SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment and Drywell Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3 Calibrate the analog trip module.

In accordance with the Surveillance Frequency Control Program (continued)

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-54 Amendment No. 192 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.7

NOTE---------------------

Channel sensors are excluded.

Verify the ISOLATION SYSTEM RESPONSE TIME for the main steam isolation valves is within limits.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.8 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-55 Amendment No. 169 Table 3.3.6.1-1 (page 1 of 6)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION F.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1. Main Steam Line Isolation

a. Reactor Vessel Water Level-Low Low Low, Level 1 1,2,3 4

G SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.7 SR 3.3.6.1.8

-148.1 inches

b. Main Steam Line Pressure-Low 1

4 H

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 841 psig

c. Main Steam Line Flow-High 1,2,3 4

G SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 284 psid

d. Condenser Vacuum-Low 1,2(a),

3(a) 4 G

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 7.6 inches Hg vacuum

e. Main Steam Tunnel Temperature-High 1,2,3 4

G SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 171°F

f. Main Steam Line Turbine Building Temperature-High 1,2,3 4

G SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 Modules 1-4 142°F, Module 5 150°F

g. Manual Initiation 1,2,3 4

J SR 3.3.6.1.6 NA (continued)

(a) With any turbine stop valve not closed.

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-56 Amendment No. 169 Table 3.3.6.1-1 (page 2 of 6)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION F.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

2. Primary Containment and Drywell Isolation

a. Reactor Vessel Water Level-Low Low, Level 2 1,2,3 (c) 4(b) 4 K

O SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8 SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

-48.1 inches

b. Drywell Pressure-High 1,2,3 4(b)

K SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 1.88 psig

c. Deleted

d. Drywell Pressure-High (ECCS Divisions 1 and 2) 1,2,3 4(b)

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 1.88 psig

e. Reactor Vessel Water Level-Low Low, Level 2 (HPCS NSPS Div 3 and 4) 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

-48.1 inches

f. Drywell Pressure-High (HPCS NSPS Div 3 and

4) 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 1.88 psig (continued)

(b) Also required to initiate the associated drywell isolation function.

(c) During operations with a potential for draining the reactor vessel.

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-57 Amendment No. 169 Table 3.3.6.1-1 (page 3 of 6)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION F.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

2. Primary Containment and Drywell Isolation (continued)

g. Containment Building Fuel Transfer Pool Ventilation Plenum Radiation-High (c),(dc) 4 N

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 500 mR/hr

h. Containment Building Exhaust Radiation-High 1,2,3 4(b)

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 400 mR/hr (c),(dc) 4 N

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 400 mR/hr

i. Containment Building Continuous Containment Purge (CCP) Exhaust Radiation-High 1,2,3 4(b)

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 400 mR/hr (c),(dc) 4 N

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 400 mR/hr

j. Reactor Vessel Water Level-Low Low Low, Level 1 1,2,3 4(b)

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

-148.1 inches (c) 4 O

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.56 SR 3.3.6.1.86

-148.1 inches

k. Containment Pressure-High (ed) 2 I

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 3.0 psid

l. Manual Initiation 1,2,3 2(b)

J SR 3.3.6.1.6 NA (c)(dc) 2 N

SR 3.3.6.1.6 NA (continued)

(b) Also required to initiate the associated drywell isolation function.

(c) During operations with a potential for draining the reactor vessel.

(dc) During movement of recently irradiated fuel assemblies in the primary or secondary containment.

(ed) MODES 1, 2, and 3 with the associated PCIVs not closed.

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-58 Amendment No. 169 Table 3.3.6.1-1 (page 4 of 6)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION F.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

3. Reactor Core Isolation Cooling (RCIC) System Isolation

a. Auxiliary Building RCIC Steam Line Flow-High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 118.5 inches water

b. RCIC Steam Line Flow-High, Time Delay 1,2,3 2

I SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 13 seconds

c. RCIC Steam Supply Line Pressure-Low 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 52 psig

d. RCIC Turbine Exhaust Diaphragm Pressure-High 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 20 psig

e. RCIC Equipment Room Ambient Temperature-High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 207°F

f. Main Steam Line Tunnel Ambient Temperature-High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 171°F

g. Main Steam Line Tunnel Temperature Timer 1,2,3 2

I SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 28 minutes

h. Reactor Vessel Water Level-Low Low, Level 2 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

-48.1 inches

i. Drywell RCIC Steam Line Flow - High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 188 inches water (continued)

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-59 Amendment No. 169 Table 3.3.6.1-1 (page 5 of 6)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION F.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

3.

RCIC System Isolation (continued)

j. Drywell Pressure - High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 1.88 psig

k. Manual Initiation 1,2,3 1

J SR 3.3.6.1.6 NA

4. Reactor Water Cleanup (RWCU) System Isolation

a. Differential Flow -

High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.6 SR 3.3.6.1.8 66.1 gpm

b. Differential Flow-Timer 1,2,3 2

I SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.6 47 seconds

c. RWCU Heat Exchanger Equipment Room Temperature-High 1,2,3 2 per room I

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 205°F

d. RWCU Pump Rooms Temperature-High 1,2,3 2 per room I

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 202°F

e. Main Steam Line Tunnel Ambient Temperature-High 1,2,3 2

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 171°F

f. Reactor Vessel Water Level-Low Low, Level 2 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

-48.1 inches (c) 4 O

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.56 SR 3.3.6.1.68

-48.1 inches

g. Standby Liquid Control System Initiation 1,2,3 2

L SR 3.3.6.1.6 NA

h. Manual Initiation 1,2,3 (c),(dc) 2 2

J N

SR 3.3.6.1.6 SR 3.3.6.1.6 NA NA (continued)

(c) During operations with a potential for draining the reactor vessel.

(dc)

During movement of recently irradiated fuel assemblies in the primary or secondary containment.

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 CLINTON 3.3-60 Amendment No. 169 Table 3.3.6.1-1 (page 6 of 6)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION F.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

5. RHR System Isolation

a. RHR Heat Exchanger Ambient Temperature-High 1,2,3 2 per room I

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 160°F

b. Reactor Vessel Water Level - Low, Level 3 1,2,3(fe) 4 I

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 8.3 inches

c. Reactor Vessel Water Level - Low, Level 3 3(gf),4,5 4(h)

M SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 8.3 inches

d. Reactor Vessel Water Level - Low Low Low, Level 1 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

-148.1 inches

e. Reactor Vessel Pressure-High 1,2,3 4

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 113 psig

f. Drywell Pressure-High 1,2,3 8

I SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 1.88 psig

g. Manual Initiation 1,2,3 2

J SR 3.3.6.1.6 NA (fe) With reactor steam dome pressure greater than or equal to the RHR cut in permissive pressure.

(gf) With reactor steam dome pressure less than the RHR cut in permissive pressure.

(h) Only one trip system required in MODES 4 and 5 with RHR Shutdown Cooling System integrity maintained.

Secondary Containment Isolation Instrumentation 3.3.6.2 CLINTON 3.3-64 Amendment No. 169 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER TRIP SYSTEM SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1.

Reactor Vessel Water Level-Low Low, Level 2 1,2,3,(a) 2 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.5 SR 3.3.6.2.6

-48.1 inches

2.

Drywell Pressure-High 1,2,3 2

SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 SR 3.3.6.2.5 1.88 psig

3.

Containment Building Fuel Transfer Pool Ventilation Plenum Exhaust Radiation-High (a),(b) 2 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 500 mR/hr

4.

Containment Building Exhaust Radiation-High 1,2,3,(a),(b) 2 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 400 mR/hr

5.

Containment Building Continuous Containment Purge (CCP) Exhaust Radiation-High 1,2,3, (a),(b) 2 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 400 mR/hr

6.

Fuel Building Exhaust Radiation-High 1,2,3, (cb) 2 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 17 mR/hr

7.

Manual Initiation 1,2,3, (a),(b) 1 SR 3.3.6.2.5 NA (a) During operations with a potential for draining the reactor vessel.

(ba) During movement of recently irradiated fuel assemblies in the primary or secondary containment.

(cb) During movement of recently irradiated fuel assemblies in the fuel building.

Control Room Ventilation System Instrumentation 3.3.7.1 CLINTON 3.3-77 Amendment No. 152 Table 3.3.7.1-1 (page 1 of 1)

Control Room Ventilation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER TRIP SYSTEM SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1. Control Room Air Intake Radiation Monitors 1,2,3, (a),(b) 1/Intake SR 3.3.7.1.1 SR 3.3.7.1.2 SR 3.3.7.1.3 26 mR/hr (a) During operations with a potential for draining the reactor vessel.

(ba) During CORE ALTERATIONS and during movement of irradiated fuel assemblies in the primary or secondary containment.

ECCS Operating 3.5.1 CLINTON 3.5-1 Amendment No. 163 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM 3.5.1 ECCS Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of seven safety/

relief valves shall be OPERABLE.

NOTE----------------------------

One low pressure coolant injection (LPCI) subsystem may be inoperable during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut in permissive pressure.

APPLICABILITY:

MODE 1, MODES 2 and 3, except ADS valves are not required to be OPERABLE with reactor steam dome pressure 150 psig.

ACTIONS

NOTE-------------------------------------

LCO 3.0.4.b is not applicable to HPCS.

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS injection/spray subsystem inoperable.

A.1 Restore low pressure ECCS injection/spray subsystem to OPERABLE status.

7 days B. High Pressure Core Spray (HPCS) System inoperable.

B.1 Verify by administrative means RCIC System is OPERABLE when RCIC is required to be OPERABLE.

AND B.2 Restore HPCS System to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days (continued)

ECCS ShutdownRPV Water Inventory Control 3.5.2 CLINTON 3.5-6 Amendment No. 133 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 ECCS ShutdownRPV Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

AND Two One ECCS injection/spray subsystems shall be OPERABLE.

NOTE----------------------------One low pressure coolant injection (LPCI) subsystem may be inoperable during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut in permissive pressure.

APPLICABILITY:

MODES 4 and, MODE 5 except with the reactor cavity to steam dryer pool gate removed and water level 22 ft 8 inches over the top of the reactor pressure vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

ROne required ECCS injection/spray subsystem inoperable.

A.1 Restore required ECCS injection/spray subsystem to OPERABLE status.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months B.

Required Action and associated Completion Time of Condition A not met.

B.1 Initiate action to establish a method of water injection capable of operating without offsite electrical power.suspend operations with a potential for draining the reactor vessel (OPDRVs).

Immediately C.

Two required ECCS injection/spray subsystems inoperable.

C.1 Initiate action to suspend OPDRVs.

AND C.2 Restore one ECCS injection/spray subsystem to OPERABLE status.

Immediately 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (continued)

ECCS ShutdownRPV Water Inventory Control 3.5.2 CLINTON 3.5-7 Amendment No. 133 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

C.1 Verify secondary containment boundary is capable of being established in less than the DRAIN TIME.

AND C.2 Verify each secondary containment penetration flow path is capable of being isolated in less than the DRAIN TIME.

AND C.3 Verify one standby gas treatment subsystem is capable of being placed in operation in less than the DRAIN TIME.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 4 hours 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (continued)

ECCS ShutdownRPV Water Inventory Control 3.5.2 CLINTON 3.5-8 Amendment No. 133 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

DRAIN TIME < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .Required Action C.2 and associated Completion Time not met.

D.1

NOTE --------

Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power.

Initiate action to establish an additional method of water injection with water sources capable of maintaining RPV water level > TAF for 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

AND D.2 Initiate action to restore establish secondary containment to OPERABLE statusboundary.

AND D.23 Initiate action to isolate each secondary containment penetration flow path or verify it can be manually isolated from the control room.

Initiate action to restore one standby gas treatment subsystem to OPERABLE status.

AND D.34 Initiate action to verify one standby gas treatment subsystem is capable of being placed in operation.

AND D.4

NOTE--------

Entry and exit is permissible under administrative control.

Initiate action to close one door in the upper containment personnel air lock.

Immediately Immediately Immediately Immediately (continued)

ECCS ShutdownRPV Water Inventory Control 3.5.2 CLINTON 3.5-9 Amendment No. 204 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition C or D not met.

OR DRAIN TIME < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

E.1 Initiate action to restore DRAIN TIME to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

In accordance with the Surveillance Frequency Control Program SR 3.5.2.12 Verify, for each a required low pressure ECCS injection/spray subsystem, the suppression pool water level is 12 ft 8 inches.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.23 Verify, for the a required High Pressure Core Spray (HPCS) System, the:

a.

Suppression pool water level is 12 ft 8 inches; or

b.

RCIC storage tank available water volume is 125,000 gal.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.34 Verify, for each the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program (continued)

ECCS ShutdownRPV Water Inventory Control 3.5.2 CLINTON 3.5-10 Amendment No. 204 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.45

NOTES-----------------

1. One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flow paths opened under administrative control.

Verify, each for the required ECCS injection/spray subsystem, each manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.56 Operate the required ECCS injection/spray subsystem through the recirculation line for 10 minutes.Verify each required ECCS pump develops the specified flow rate with the specified pump differential pressure.

PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS 5010 gpm 290 psid LPCI 5050 gpm 113 psid HPCS 5010 gpm 363 psid In accordance with the Surveillance Frequency Control Program SR 3.5.2.7 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.68

NOTE--------------------

Vessel injection/spray may be excluded.

Verify each the required ECCS injection/spray subsystem can be manually operated.actuates on an actual or simulated automatic initiation signal.

In Accordance with the Surveillance Frequency Control Program

RCIC System 3.5.3 CLINTON 3.5-11 Amendment No. XXX 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

NOTE-------------------------------------

LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable.

A.1 Verify by administrative means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days B. Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

AND B.2 Reduce reactor steam dome pressure to 150 psig.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program (continued)

RCIC System 3.5.3 CLINTON 3.5-12 Amendment No. XXX SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.2

NOTE--------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.3

NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure 1045 psig and 920 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.4

NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure 150 psig and 135 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.5

NOTE--------------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal.

In accordance with the Surveillance Frequency Control Program

Primary Containment Air Locks 3.6.1.2 CLINTON 3.6-3 Amendment No. 147 3.6 CONTAINMENT SYSTEMS 3.6.1.2 Primary Containment Air Locks LCO 3.6.1.2 Each primary containment air lock shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3,

NOTE------------------------------

The following Applicabilityies appliesy only to the upper containment personnel air lock.

During movement of recently irradiated fuel assemblies in the primary or secondary containment, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS

NOTES------------------------------------

1. Entry and exit is permissible to perform repairs of the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when air lock leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, and 3.

(continued)

Primary Containment Air Locks 3.6.1.2 CLINTON 3.6-7 Amendment No. 147 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition A, B, or C not met during movement of recently irradiated fuel assemblies in the primary or secondary containment, or OPDRVs.

NOTE------------

LCO 3.0.3 is not applicable.

E.1 Suspend movement of recently irradiated fuel assemblies in the primary and secondary containment.

AND E.2 Initiation action to suspend OPDRVs.

Immediately Immediately

PCIVs 3.6.1.3 CLINTON 3.6-9 Amendment No. 158 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

LCO 3.6.1.3 Each PCIV shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, MODES 4 and 5 for RHR Shutdown Cooling System suction from the reactor vessel isolation valves when associated isolation instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment and Drywell Isolation Instrumentation," Function 5.c.

NOTE------------------------------

The following Applicabilityies apply applies only to secondary containment bypass leakage isolation valves.

During movement of recently irradiated fuel assemblies in the primary or secondary containment, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS

NOTES------------------------------------

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, and 3.

5. Not applicable for the Inclined Fuel Transfer System (IFTS) penetration when the associated primary containment blind flange is removed, provided that the fuel building fuel transfer pool water is maintained el. 753 ft., the steam dryer pool to reactor cavity pool gate is installed with the seal inflated and a backup air supply provided, the total time the flange is open does not exceed 40 days per operating cycle, and the IFTS transfer tube drain valve(s) remain(s) closed, except that the IFTS tube drain valve(s) may be opened under administrative controls.

(continued)

PCIVs 3.6.1.3 CLINTON 3.6-14 Amendment No. 147 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued)

D.3 Perform SR 3.6.1.3.5 for the resilient seal purge valves closed to comply with Required Action D.1.

Once per 92 days E. Required Action and associated Completion Time of Condition A, B, C, or D not met in MODE 1, 2, or 3.

E.1 Be in MODE 3.

AND E.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours F. Required Action and associated Completion Time of Condition A, B, C, or D not met for PCIV(s) required to be OPERABLE during movement of recently irradiated fuel assemblies in the primary or secondary containment.

F.1

NOTE---------

LCO 3.0.3 is not applicable.

Suspend movement of recently irradiated fuel assemblies in primary and secondary containment.

Immediately G. Required Action and associated Completion Time of Condition A, B, C, or D not met for PCIV(s) required to be OPERABLE during MODE 4 or 5 or during OPDRVs.

G.1 Initiate action to suspend OPDRVs.

OR G.2 Initiate action to restore valve(s) to OPERABLE status.

Immediately Immediately (continued)

Secondary Containment 3.6.4.1 CLINTON 3.6-43 Amendment No. 187 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of recently irradiated fuel assemblies in the primary or secondary containment, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Secondary containment inoperable in MODE 1, 2, or 3.

A.1 Restore secondary containment to OPERABLE status.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months B.

Required Action and associated Completion Time of Condition A not met.

NOTE------------

LCO 3.0.4.a is not applicable when entering MODE 3.

B.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Secondary Containment 3.6.4.1 CLINTON 3.6-44 Amendment No. 192 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment inoperable during movement of recently irradiated fuel assemblies in the primary or secondary containment, or during OPDRVs.

C.1

NOTE---------

LCO 3.0.3 is not applicable.

Suspend movement of recently irradiated fuel assemblies in the primary and secondary containment.

AND C.2 Initiate action to suspend OPDRVs.

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is 0.25 inch of vacuum water gauge.

In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.2 Verify all secondary containment equipment hatches are closed and sealed.

In accordance with the Surveillance Frequency Control Program (continued)

SCIDs 3.6.4.2 CLINTON 3.6-47 Amendment No. 147 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Dampers (SCIDs)

LCO 3.6.4.2 Each SCID shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of recently irradiated fuel assemblies in the primary or secondary containment, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS

NOTES------------------------------------

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIDs.

(continued)

SCIDs 3.6.4.2 CLINTON 3.6-49 Amendment No. 147 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and associated Completion Time of Condition A or B not met during movement of recently irradiated fuel assemblies in the primary or secondary containment, or during OPDRVs.

D.1

NOTE---------

LCO 3.0.3 is not applicable.

Suspend movement of recently irradiated fuel assemblies in the primary and secondary containment.

AND D.2 Initiate action to suspend OPDRVs.

Immediately Immediately

SGT System 3.6.4.3 CLINTON 3.6-51 Amendment No. 187 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of recently irradiated fuel assemblies in the primary or secondary containment, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem inoperable.

A.1 Restore SGT subsystem to OPERABLE status.

7 days B. Required Action and associated Completion Time of Condition A not met in MODE 1, 2, or 3.

NOTE------------

LCO 3.0.4.a is not applicable when entering MODE 3.

B.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

SGT System 3.6.4.3 CLINTON 3.6-52 Amendment No. 187 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and associated Completion Time of Condition A not met during movement of recently irradiated fuel assemblies in the primary or secondary containment, or during OPDRVs.

NOTE------------

LCO 3.0.3 is not applicable.

C.1 Place OPERABLE SGT subsystem in operation.

OR C.2.1 Suspend movement of recently irradiated fuel assemblies in the primary and secondary containment.

AND C.2.2 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately D.

Two SGT subsystems inoperable in MODE 1, 2, or 3.

NOTE------------

LCO 3.0.4.a is not applicable when entering MODE 3.

D.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

SGT System 3.6.4.3 CLINTON 3.6-53 Amendment No. 201 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two SGT subsystems inoperable during movement of recently irradiated fuel assemblies in the primary or secondary containment, or during OPDRVs.

E.1 Suspend movement of recently irradiated fuel assemblies in the primary and secondary containment.

AND E.2 Initiate action to suspend OPDRVs.

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for 15 continuous minutes with heaters operating.

In accordance with the Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual or simulated initiation signal.

In accordance with the Surveillance Frequency Control Program SR 3.6.4.3.4 Verify each SGT filter cooling bypass damper can be opened and the fan started.

In accordance with the Surveillance Frequency Control Program

Control Room Ventilation System 3.7.3 CLINTON 3.7-4 Amendment No. 95 3.7 PLANT SYSTEM 3.7.3 Control Room Ventilation System LCO 3.7.3 Two Control Room Ventilation subsystems shall be OPERABLE.

NOTE---------------------------

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the primary or secondary containment, During CORE ALTERATIONS, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Control Room Ventilation subsystem inoperable for reasons other than Condition C.

A.1 Restore Control Room Ventilation subsystem to OPERABLE status.

7 days B. Required Action and associated Completion Time of Condition A not met in MODE 1, 2, or 3.

NOTE-------------

LCO 3.0.4.a is not applicable when entering MODE 3.

B.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. One or more Control Room Ventilation subsystems inoperable due to inoperable CRE boundary in MODE 1, 2, or 3.

C.1 Initiate action to implement mitigating actions.

AND C.2 Verify mitigating actions ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND C.3 Restore CRE boundary to OPERABLE status.

Immediately 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 90 days (continued)

Control Room Ventilation System 3.7.3 CLINTON 3.7-5 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and Associated Completion Time of Condition C not met in MODE 1, 2, or 3.

D.1 Be in MODE 3.

AND D.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours E. Required Action and associated Completion Time of Condition A not met during movement of irradiated fuel assemblies in the primary or secondary containment, or during CORE ALTERATIONS, or during OPDRVs.

NOTE-------------

LCO 3.0.3 is not applicable.

E.1 Place OPERABLE Control Room Ventilation subsystem in high radiation mode.

OR E.2.1 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND E.2.2 Suspend CORE ALTERATIONS.

AND E.2.3 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately Immediately F. Two Control Room Ventilation subsystems inoperable in MODE 1, 2, or 3 for reasons other than Condition C.

NOTE-------------

LCO 3.0.4.a is not applicable when entering MODE 3.

F.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Control Room Ventilation System 3.7.3 CLINTON 3.7-6 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Two Control Room Ventilation subsystems inoperable during movement of irradiated fuel assemblies in the primary or secondary containment, or during CORE ALTERATIONS, or during OPDRVs.

OR One or more Control Room Ventilation subsystems inoperable due to inoperable CRE boundary during movement of irradiated fuel assemblies in the primary or secondary containment, or during CORE ALTERATIONS, or during OPDRVs.

G.1 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND G.2 Suspend CORE ALTERATIONS.

AND G.3 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Operate each Control Room Ventilation subsystem with flow through the makeup filter for 15 continuous minutes with the heaters operating.

In accordance with the Surveillance Frequency Control Program SR 3.7.3.2 Operate each Control Room Ventilation subsystem with flow through the recirculation filter for 15 minutes.

In accordance with the Surveillance Frequency Control Program (continued)

Control Room AC System 3.7.4 CLINTON 3.7-8 Amendment No. 95 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two control room AC subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the primary or secondary containment, During CORE ALTERATIONS, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC subsystem inoperable.

A.1 Restore control room AC subsystem to OPERABLE status.

30 days B. Two control room AC subsystems inoperable.

B.1 Verify control room area temperature 86 ºF.

AND B.2 Restore one control room AC subsystem to OPERABLE status.

Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 7 days C. Required Action and Associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.

NOTE------------

LCO 3.0.4.a is not applicable when entering MODE 3.

C.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Control Room AC System 3.7.4 CLINTON 3.7-9 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and associated Completion Time of Condition A not met during movement of irradiated fuel assemblies in the primary or secondary containment, or during CORE ALTERATIONS, or during OPDRVs.

NOTE-------------

LCO 3.0.3 is not applicable.

D.1 Place OPERABLE control room AC subsystem in operation.

OR D.2.1 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND D.2.2 Suspend CORE ALTERATIONS.

AND D.2.3 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately Immediately (continued)

Control Room AC System 3.7.4 CLINTON 3.7-10 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition B not met during movement of irradiated fuel assemblies in the primary or secondary containment, or during CORE ALTERATIONS, or during OPDRVs.

NOTE-------------

LCO 3.0.3 is not applicable.

E.1 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND E.2 Suspend CORE ALTERATIONS.

AND E.3 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room AC subsystem has the capability to remove the assumed heat load.

In accordance with the Surveillance Frequency Control Program

AC Sources Shutdown 3.8.2 CLINTON 3.8-16 Amendment No. XXX 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a.

One qualified circuit between the offsite transmission network and the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems Shutdown";

b.

One diesel generator (DG) capable of supplying one division of the Division 1 or 2 onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10; and

c.

One qualified circuit, other than the circuit in LCO 3.8.2.a, between the offsite transmission network and the Division 3 onsite Class 1E AC electrical power distribution subsystem, or the Division 3 DG capable of supplying the Division 3 onsite Class 1E AC electrical power distribution subsystem, when the High Pressure Core Spray System is OPERABLE for compliance with LCO 3.5.2, ECCS-ShutdownRPV Water Inventory Control.

APPLICABILITY:

MODES 4 and 5, During movement of irradiated fuel assemblies in the primary or secondary containment.

ACTIONS

NOTE----------------------------------

LCO 3.0.3 is not applicable.

(continued)

AC Sources Shutdown 3.8.2 CLINTON 3.8-17 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. LCO Item a not met.

NOTE-------------

Enter applicable Condition and Required Actions of LCO 3.8.10, when any required division is de-energized as a result of Condition A.

A.1 Declare affected required feature(s) with no offsite power available from a required circuit inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND A.2.2 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel (OPDRVs).

AND A.2.43 Initiate action to restore required offsite power circuit to OPERABLE status.

Immediately Immediately Immediately Immediately Immediately (continued)

AC Sources Shutdown 3.8.2 CLINTON 3.8-18 Amendment No. 95 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. LCO Item b not met.

B.1 Suspend CORE ALTERATIONS.

AND B.2 Suspend movement of irradiated fuel assemblies in primary and secondary containment.

AND B.3 Initiate action to suspend OPDRVs.

AND B.43 Initiate action to restore required DG to OPERABLE status.

Immediately Immediately Immediately Immediately C. LCO Item c not met.

C.1 Declare High Pressure Core Spray System inoperable.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

DC Sources Shutdown 3.8.5 CLINTON 3.8-27 Amendment No. XXX 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources Shutdown LCO 3.8.5 The following shall be OPERABLE:

a.

One Class 1E DC electrical power subsystem capable of supplying one division of the Division 1 or 2 onsite Class 1E DC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems -

Shutdown";

b.

One Class 1E battery or battery charger, other than the DC electrical power subsystem in LCO 3.8.5.a, capable of supplying the remaining Division 1 or Division 2 onsite Class 1E DC electrical power distribution subsystem(s) when required by LCO 3.8.10; and

c.

The Division 3 and 4 DC electrical power subsystems capable of supplying the Division 3 and 4 onsite Class 1E DC electrical power distribution subsystems, when the High Pressure Core Spray System is OPERABLE for compliance with LCO 3.5.2, ECCS-ShutdownRPV Water Inventory Control.

APPLICABILITY:

MODES 4 and 5, During movement of irradiated fuel assemblies in the primary or secondary containment.

ACTIONS

NOTE-------------------------------------

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One battery charger on one division inoperable.

A.1 Restore battery terminal voltage to greater than or equal to the minimum established float voltage.

AND A.2 Verify battery float current < 2 amps.

AND A.3 Restore battery charger to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 7 days (continued)

DC Sources Shutdown 3.8.5 CLINTON 3.8-28 Amendment No. 142 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more required DC electrical power subsystems inoperable for reasons other than Condition A.

OR Required Action and associated Completion Time of Condition A not met.

B.1 Declare affected required feature(s) inoperable.

OR B.2.1 Suspend CORE ALTERATIONS.

AND Immediately Immediately B.2.2 Suspend movement of irradiated fuel assemblies in the primary and secondary containment.

AND Immediately B.2.3 Initiate action to suspend operations with a potential for draining the reactor.

Immediately AND B.2.43 Initiate action to restore required DC electrical power subsystems to OPERABLE status.

Immediately

Inverters-Shutdown 3.8.8 CLINTON 3.8-36 Amendment No. XXX 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters Shutdown LCO 3.8.8 The following Divisional inverters shall be OPERABLE:

a.

One Divisional inverter capable of supplying one division of the Division 1 or 2 onsite Class 1E uninterruptible AC bus electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown"; and

b.

The Division 3 and 4 Divisional inverters capable of supplying the Division 3 and 4 onsite Class 1E uninterruptible AC bus electrical power distribution subsystems, when the High Pressure Core Spray System is OPERABLE for compliance with LCO 3.5.2, ECCS-ShutdownRPV Water Inventory Control.

APPLICABILITY:

MODES 4 and 5, During movement of irradiated fuel assemblies in the primary or secondary containment.

Inverters Shutdown 3.8.8 CLINTON 3.8-37 Amendment No. 95 ACTIONS

NOTE-------------------------------

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required divisional inverters inoperable.

A.1 Declare affected required feature(s) inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND Immediately Immediately A.2.2 Suspend handling of irradiated fuel assemblies in the primary and secondary containment.

AND Immediately A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel.

AND Immediately A.2.43 Initiate action to restore required divisional inverters to OPERABLE status.

Immediately

Distribution Systems Shutdown 3.8.10 CLINTON 3.8-43 Amendment No. 192 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel.

AND A.2.43 Initiate actions to restore required AC, DC, and uninterruptible AC bus electrical power distribution subsystems to OPERABLE status.

AND A.2.54 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.

Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required AC, DC, and uninterruptible AC bus electrical power distribution subsystems.

In accordance with the Surveillance Frequency Control Program

Clinton Power Station, Unit 1 Supplement to Clinton Power Station, Unit 1 Application to Revise Technical Specifications to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control" ATTACHMENT 3 REVISED TECHNICAL SPECIFICATIONS PAGES TOC Page ii TOC Page iii TOC Page iv 1.0-1 1.0-2 1.0-3 1.0-4 1.0-5 3.3-32 3.3-33 3.3-35 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-43a 3.3-43b 3.3-43c 3.3-43d 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.3-56 3.3-57 3.3-58 3.3-59 3.3-60 3.3-64 3.3-77 3.5-1 3.5-6 3.5-7 3.5-8 3.5-9 3.5-10 3.5-11 3.5-12 3.6-3 3.6-7 3.6-9 3.6-14 3.6-43 3.6-44 3.6-47 3.6-49 3.6-51 3.6-52 3.6-53 3.7-4 3.7-5 3.7-6 3.7-8 3.7-9 3.7-10 3.8-16 3.8-17 3.8-18 3.8-27 3.8-28 3.8-36 3.8-37 3.8-43

TABLE OF CONTENTS CLINTON Revision No. 14-2 ii 3.2 POWER DISTRIBUTION LIMITS (continued) 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)...........................3.2-2 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)...........................3.2-3 B 3.2 POWER DISTRIBUTION LIMITS.....................................B 3.2-1 B 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)..................................................B 3.2-1 B 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)...........................B 3.2-5 B 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)............................B 3.2-9 3.3 INSTRUMENTATION...............................................3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation...........3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation................3.3-10 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation....3.3-14a 3.3.2.1 Control Rod Block Instrumentation.........................3.3-15 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation............3.3-19 3.3.3.2 Remote Shutdown System....................................3.3-23 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation.......................................3.3-25 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation..................3.3-28 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation......3.3-31 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation................................... 3.3-43a 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation................................... 3.3-44 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation.3.3-48 3.3.6.2 Secondary Containment Isolation Instrumentation...........3.3-61 3.3.6.3 Residual Heat Removal (RHR) Containment Spray System Instrumentation.......................................3.3-65 3.3.6.4 Suppression Pool Makeup (SPMU) System Instrumentation.....3.3-69 3.3.6.5 Relief and Low-Low Set (LLS) Instrumentation..............3.3-74 3.3.7.1 Control Room Ventilation System Instrumentation...........3.3-75 3.3.8.1 Loss of Power (LOP) Instrumentation.......................3.3-78 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring.3.3-81 B 3.3 INSTRUMENTATION............................................. B 3.3-1 B 3.3.1.1 Reactor Protection System (RPS) Instrumentation......... B 3.3-1 B 3.3.1.2 Source Range Monitor (SRM) Instrumentation.............. B 3.3-31 B 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation.. B 3.3-39a B 3.3.2.1 Control Rod Block Instrumentation....................... B 3.3-40 B 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation.......... B 3.3-49 (continued)

TABLE OF CONTENTS CLINTON Revision No. 2-13 iii B 3.3 INSTRUMENTATION (continued)

B 3.3.3.2 Remote Shutdown System....................................B 3.3-60 B 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation...........................................B 3.3-65 B 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation........B 3.3-76 B 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation......B 3.3-85 B 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation...................................... B 3.3-122a B 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation...................................... B 3.3-123 B 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation.........................B 3.3-135 B 3.3.6.2 Secondary Containment Isolation Instrumentation...........B 3.3-174 B 3.3.6.3 Residual Heat Removal (RHR) Containment Spray System Instrumentation...........................................B 3.3-186 B 3.3.6.4 Suppression Pool Makeup (SPMU) System Instrumentation.....B 3.3-197 B 3.3.6.5 Relief and Low-Low Set (LLS) Instrumentation..............B 3.3-208 B 3.3.7.1 Control Room Ventilation (CRV) System Instrumentation.....B 3.3-215 B 3.3.8.1 Loss of Power (LOP) Instrumentation.......................B 3.3-222 B 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring.....................................B 3.3-230 3.4 REACTOR COOLANT SYSTEM (RCS)..................................3.4-1 3.4.1 Recirculation Loops Operating.............................3.4-1 3.4.2 Flow Control Valves (FCVs)................................3.4-6 3.4.3 Jet Pumps.................................................3.4-8 3.4.4 Safety/Relief Valves (S/RVs)..............................3.4-10 3.4.5 RCS Operational LEAKAGE...................................3.4-12 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage................3.4-14 3.4.7 RCS Leakage Detection Instrumentation.....................3.4-17 3.4.8 RCS Specific Activity.....................................3.4-20 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown......................................3.4-22 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown.....................................3.4-25 3.4.11 RCS Pressure and Temperature (P/T) Limits.................3.4-27 3.4.12 Reactor Steam Dome Pressure...............................3.4-33 B 3.4 REACTOR COOLANT SYSTEM (RCS)..................................B 3.4-1 B 3.4.1 Recirculation Loops Operating.............................B 3.4-1 B 3.4.2 Flow Control Valves (FCVs)................................B 3.4-9 (continued)

TABLE OF CONTENTS CLINTON Revision No. 14-2 iv B 3.4 REACTOR COOLANT SYSTEM (RCS) (continued)

B 3.4.3 Jet Pumps.................................................B 3.4-13 B 3.4.4 Safety/Relief Valves (S/RVs)..............................B 3.4-17 B 3.4.5 RCS Operational LEAKAGE...................................B 3.4-23 B 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage................B 3.4-28 B 3.4.7 RCS Leakage Detection Instrumentation.....................B 3.4-33 B 3.4.8 RCS Specific Activity.....................................B 3.4-39 B 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown..................................B 3.4-43 B 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown.................................B 3.4-48 B 3.4.11 RCS Pressure and Temperature (P/T) Limits.................B 3.4-53 B 3.4.12 Reactor Steam Dome Pressure...............................B 3.4-63 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM.........................................3.5-1 3.5.1 ECCS - Operating...........................................3.5-1 3.5.2 RPV Water Inventory Control...............................3.5-6 3.5.3 RCIC System...............................................3.5-11 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM.........................................B 3.5-1 B 3.5.1 ECCS - Operating...........................................B 3.5-1 B 3.5.2 RPV Water Inventory Control...............................B 3.5-17 B 3.5.3 RCIC System...............................................B 3.5-27 3.6 CONTAINMENT SYSTEMS...........................................3.6-1 3.6.1.1 Primary Containment.......................................3.6-1 3.6.1.2 Primary Containment Air Locks.............................3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs)..............3.6-9 3.6.1.4 Primary Containment Pressure..............................3.6-20 3.6.1.5 Primary Containment Air Temperature.......................3.6-21 3.6.1.6 Low-Low Set (LLS) Valves..................................3.6-22 3.6.1.7 Residual Heat Removal (RHR) Containment Spray System......3.6-24 3.6.1.8 Deleted...................................................3.6-26 3.6.1.9 Feedwater Leakage Control System (FWLCS)..................3.6-27a 3.6.2.1 Suppression Pool Average Temperature......................3.6-28 3.6.2.2 Suppression Pool Water Level..............................3.6-31 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling......3.6-32 3.6.2.4 Suppression Pool Makeup (SPMU) System.....................3.6-34 3.6.3.1 Deleted.................................................3.6-36 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters.........3.6-38 (continued)