Text

Operational Requirements Manual (Orm) 2013
	ML13016A360
Person / Time
Site:	Clinton
Issue date:	01/10/2013
From:	; Exelon Generation Co
To:	; Office of Nuclear Reactor Regulation
References
	RS-13-009
	Download: ML13016A360 (165)
	v • d • e

Clinton Power Station Operational Requirements Manual (ORM) 2013 Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 NRC Docket No. STN 50-461

CPS OPERATIONAL REQUIREMENTS MANUAL TABLE OF CONTENTS Page Rev.

No. No.

1.0 DEFINITIONS/REQUIREMENTS 67 1.0 Purpose 1 1.1 Definitions 1-3 1.2 General Operational Requirements 4-5 1.3 General Testing Requirements 6-8 2.0/3.0/ OPERATIONAL REQUIREMENTS/ACTIONS/

4.0/5.0 TESTING REQUIREMENTS/BASES 2.1 REACTIVITY CONTROL SYSTEMS 74 2.1.1 Control Rod Drive Housing Support 1 2.1.2 Control Rod Scram Accumulators 2 2.2 INSTRUMENTATION 74 2.2.1 APRM - Control Rod Block 1-3 Instrumentation 2.2.2 SRM - Control Rod Block 4-6 Instrumentation 2.2.3 IRM - Control Rod Block 7-9 Instrumentation 2.2.4 Scram Discharge Volume - Control 10-11 Rod Block Instrumentation 2.2.5 Reactor Coolant System Recirculation 12-13 Flow - Control Rod Block Instrumentation 2.2.6 Area Radiation Monitoring 14-15 Instrumentation 2.2.7 Seismic Monitoring Instrumentation 16-19 2.2.8 Meteorological Monitoring 20-21 Instrumentation 2.2.9 Traversing In-Core Probe System 22-23 2.2.10 Deleted 24 2.2.11 Main Condenser Offgas Treatment 25-26 System Explosive Gas Monitoring Instrumentation 2.2.12 Feedwater System/Main Turbine Trip 27-28 2.2.13 ADS Accumulator Low Pressure 29 Alarm System Instrumentation Table of Contents Page 1 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL Page Rev.

No. No.

2.2 INSTRUMENTATION (CONT.)

2.2.14 NSPS Self Test System 30-31 2.2.15 Suppression Pool Water Temperature Indicators 32 Instrumentation 2.2.16 Main Steam Line Radiation 33-34 Monitoring Instrumentation 2.2.17 Hydrogen Monitoring Equipment 35 2.3 REACTOR COOLANT SYSTEMS 65 2.3.1 Reactor Coolant System Chemistry 1-3 2.4 PLANT SYSTEMS 74 2.4.1 Snubbers 1-4 2.4.2 Sealed Source Contamination 5-6 2.4.3 Deleted 2.4.4 Liquid Storage Tanks 7-8 2.4.5 Main Condenser Offgas Hydrogen 9 Monitoring 2.4.6 Drywell Post-LOCA Vacuum 10 Relief Valves 2.4.7 Deleted 2.4.8 Spent Fuel Storage, Cask Storage 11 and Upper Containment Pools 2.4.9 Essential Switchgear Room Ventilation 12-13 2.4.10 Primary Containment Hydrogen 14 Recombiner 2.5 ELECTRICAL POWER SYSTEMS 70 2.5.1 Containment Penetration Conductor 1-3 Overcurrent Protective Devices 2.5.2 Motor Operated Valves Thermal 4 Overload Protection 2.5.3 Electrical Power Systems 5-6 Table of Contents Page 2 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL Page Rev.

No. No.

2.6 REFUELING OPERATIONS 71 2.6.1 Decay Time - Refueling Operations 1 2.6.2 Communications - Refueling Operations 2 2.6.3 Refueling Platform - Refueling Operations 3-4 2.6.4 Deleted 5 2.6.5 Crane Travel-Spent Fuel Storage 6-7 Pool, Cask Storage Pool, Upper Containment Fuel Pool and New Fuel Storage Vault -

Refueling Operations 2.6.6 Inclined Fuel Transfer System - 8-9 Refueling Operations 2.6.7 Mode Switch Position 10 6.0 ADMINISTRATIVE REQUIREMENTS 1-8 42 ATTACHMENTS 1 Remote Shutdown Instruments and Controls 1-4 75 2 Trip Setpoint Tables 1-25 72 3 Motor Operated Valves Thermal Overload Protection 1-6 69 4 Containment Isolation Valves 1-36 75 5 Drywell Isolation Valves 1-3 69 6 Secondary Containment Isolation Dampers 1 42 Table of Contents Page 3 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 1.0 PURPOSE The purpose of this manual is to specify requirements which have been removed from the Clinton Technical Specifications as a result of the conversion to Improved Technical Specifications.

1.1 DEFINITIONS ACTION 1.1.1 ACTION shall be that part of an Operational Requirement that prescribes required actions to be taken under designated conditions with specified completion times.

ACTUAL TRIP SETPOINT (ATSP) 1.1.2 The actual trip value of the sensed process variable found in the conclusion of the setpoint calculation. It is equivalent to or more conservative than the Nominal Trip Setpoint (NTSP). The ATSP, as such, may provide additional margin to the process or analytical limit.

CHANNEL CALIBRATION 1.1.3 A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds with 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 1.1.4 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.

Section 1 Page 1 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CHANNEL FUNCTIONAL TEST 1.1.5 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 OPERABILITY. The CHANNEL FUNCTION TEST may be performed by means of any series of sequential, overlapping, or total channel steps.

CORE ALTERATION 1.1.6 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.

FUNCTIONAL-FUNCTIONALITY 1.1.7 A system, subsystem, train, component, or device shall be FUNCTIONAL or have FUNCTIONALITY when it is capable of performing its specified function, as set forth in the current licensing basis.

FUNCTIONALITY does not apply to specified safety functions, but does apply to the ability of non-TS SSCs to perform other specified functions that have a necessary support function.

LOGIC SYSTEM FUNCTIONAL TEST 1.1.8A LOGIC SYSTEM FUNCTIONAL TEST shall be a 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.

MODE 1.1.9 A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning with fuel in the reactor vessel as specified in the CPS Technical Specifications.

Section 1 Page 2 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

NOMINAL TRIP SETPOINT (NTSP) 1.1.10 The calculated limiting value of the sensed process variable at which a trip could have been set. The actual trip value (ATSP) may be more conservative than the limiting value.

RATED THERMAL POWER 1.1.11 RATED THERMAL POWER (RTP) shall be a total reactor core heat transfer rate to the reactor coolant of 3473 MWt.

SELF TEST SYSTEM 1.1.12 The SELF TEST SYSTEM (STS) shall be that automatic test system designed to continually monitor the solid state nuclear system protection system (NSPS) functional circuitry by injecting short-duration pulses into circuits and verifying proper circuit response to various input combinations. The SELF TEST SYSTEM is designed to maintain surveillance over all NSPS cabinet circuitry essential to the Reactor Protection System, Emergency Core Cooling Systems, Reactor Core Isolation Cooling System, and the Nuclear Steam Supply Shutoff System on a continuous cyclic basis.

The SELF TEST SYSTEM may be used to perform various surveillance testing functions to satisfy technical specifications requirements for those components it is designed to monitor. The STS may be used to augment conventional testing methods to perform CHANNEL CHECKS, CHANNEL FUNCTIONAL TESTS, CHANNEL CALIBRATIONS, RESPONSE TIME TESTS and LOGIC SYSTEM FUNCTIONAL TESTS provided that OPERABILITY of the STS has first been verified.

SITE BOUNDARY 1.1.13 The SITE BOUNDARY shall be that line beyond which the land is neither owned, nor leased, nor otherwise controlled by the licensee.

Section 1 Page 3 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 1.2 GENERAL OPERATIONAL REQUIREMENTS 1.2.1 Operational Requirements shall be met during the MODES or other specified conditions in the Applicability, except as provided in Operational Requirement 1.2.2.

1.2.2 Upon discovery of a failure to meet an Operational Requirement, the ACTION requirements of the associated Operational Requirement shall be met. If the Operational Requirement is met or is no longer applicable prior to expiration of the specified completion time(s), completion of the ACTION(s) requirements is not required, unless otherwise stated.

1.2.3 When an Operational Requirement is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to:

a. Implement appropriate compensatory actions as needed;

b. Verify that the plant is not in an unanalyzed condition or that a required safety function is not compromised by the inoperabilites, and

c. Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , obtain Shift Operations Superintendent or designee approval of the compensatory actions and the plan for exiting the Operational Requirement 1.2.3.

Exceptions to this requirement are stated in the individual Operational Requirements.

Where corrective measures are completed that permit operation in accordance with the Operational Requirement or ACTIONS, completion of the actions required by this requirement is not required.

This requirement is only applicable in MODES 1, 2, and 3.

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

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

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and Section 1 Page 4 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 1.2 GENERAL OPERATIONAL REQUIREMENTS (Contd) establishment of risk management actions, if appropriate; exceptions to this requirement are stated in the individual Operational Requirements, or

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

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

1.2.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to Operational Requirement 1.2.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

Section 1 Page 5 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 1.3 GENERAL TESTING REQUIREMENTS 1.3.1 Testing Requirements shall be met during the MODES or other specified conditions in the Applicability for individual Operational Requirements, unless otherwise stated in the Testing Requirement. Failure to meet a Testing Requirement, whether such failure is experienced during the performance of the Testing Requirement or between performances of the Testing Requirement, shall be failure to meet the Operational Requirement. Failure to perform a Testing Requirement within the specified Frequency shall be failure to meet the Operational Requirement, except as provided in Testing Requirement 1.3.3. Testing Requirements do not have to be performed on inoperable equipment or variables outside specified limits.

1.3.2 The specified Frequency for each Testing Requirement is met if the Testing Requirement is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If an ACTION requires periodic performance on a "once per ..." basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Testing Requirement are stated in the individual Operational Requirements.

1.3.3 If it is discovered that a Testing Requirement was not performed within its specified Frequency, then compliance with the requirement to declare the Operational Requirement not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Testing Requirement. A risk evaluation shall be performed for any Testing Requirement delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Testing Requirement is not performed within the delay period, the Operational Requirement must immediately be declared not met, and the applicable ACTIONS must be entered.

When the Testing Requirement is performed within the delay period and the Testing Requirement is not met, the Operational Requirement must immediately be declared not met, and the applicable ACTION(s) must be entered.

1.3.4 Entry into a MODE or other specified condition in the Applicability of an Operational Requirement shall only be made when the Operational Requirements Testing Requirements have been met within their specified Frequency, except as provided by Operational Requirement 1.2.3. When an Operational Requirement is not met due to Testing Requirements not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with Operational Requirement 1.2.4.

Section 1 Page 6 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 1.3 GENERAL TESTING REQUIREMENTS (Contd)

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

1.3.5 Testing Requirements for inservice inspection and testing of ASME Code Class 1, 2, and 3 components shall be applicable as follows:

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

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

ASME Boiler and Pressure Vessel Code Required frequencies for and applicable Addenda terminology for performing inservice inspection inservice inspection and testing activities and testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days

c. The provisions of Testing Requirement 1.3.2 are applicable to the above required frequencies for performing inservice inspection activities.

d. Performance of the above inservice inspection and testing activities shall be in addition to other Technical Specification Surveillance Requirements and Operational Requirements Manual Testing Requirements.

e. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any Operational Requirement.

f. The Inservice Inspection Program for piping identified in NRC Generic Letter 88-01 shall be performed in accordance with the NRC Staff positions on schedule except for Category 'D' welds, methods and personnel, and sample expansion included in the generic letter.

Section 1 Page 7 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 1.3 GENERAL TESTING REQUIREMENTS (Contd)

For Category 'D' welds, BWR Owner's Group Vessel Internal Project (VIP) document BWRVIP-75 schedule shall be utilized.

Section 1 Page 8 Rev. 67 October 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.0 OPERATIONAL REQUIREMENTS 2.1 REACTIVITY CONTROL SYSTEMS 2.1.1 CONTROL ROD DRIVE HOUSING SUPPORT OPERATIONAL REQUIREMENTS Refer to USAR Section 4.6.1.2.3.

Section 2.1 Page 1 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.1.2 Deleted.

Section 2.1 Page 2 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2 INSTRUMENTATION 2.2.1 AVERAGE POWER RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION OPERATIONAL REQUIREMENT The APRM control rod block instrumentation channels in Table 2.2.1-1 shall be OPERABLE with their trip setpoints set consistent with the values specified in Table 3.2.1-1.

APPLICABILITY TABLE 2.2.1-1 APRM APPLICABILITY MINIMUM OPERABLE APPLICABLE TRIP FUNCTION CHANNELS PER TRIP FUNCTION* MODES

a. Flow Biased Upscale 3 1

b. Inoperative 3 1, 2

c. Downscale 3 1

d. Upscale, Startup 3 2

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided at least one other OPERABLE channel in the same trip function is monitoring that parameter.

ACTION 3.2.1 With the number of OPERABLE Channels:

a. One less than required by the minimum OPERABLE channels per trip function requirement, restore the inoperable channel to OPERABLE status within 7 days or place the inoperable channel in the tripped condition within the next hour.

b. Two or more less than required by the minimum OPERABLE channels per trip function requirement, place at least one inoperable channel in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Section 2.2 Page 1 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.1 AVERAGE POWER RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION (continued)

TABLE 3.2.1-1 APRM TRIP SETPOINTS TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE

a. Flow Biased Upscale

1) During two recirculation loop operation:

a) Flow Biased 0.58 W + 50%** with a < 0.55 W + 56%** with a maximum of maximum of b) High Flow Clamped < 108.0% of RATED < 110.0% of RATED THERMAL POWER THERMAL POWER

2) During single recirculation loop operation:

a) Flow Biased 0.58 (W-W) + 32%** < 0.55 (W-W) + 37.5%**

b) High Flow Clamped Not required OPERABLE Not required OPERABLE

b. Inoperative NA NA

c. Downscale > 5% of RATED > 3% OF RATED THERMAL POWER THERMAL POWER

d. Upscale Startup < 12% of RATED < 14% of RATED THERMAL POWER THERMAL POWER

- The Average Power Range Monitor rod block function is varied as a function of recirculation loop flow (W).

The trip setting of this function must be maintained in accordance with note (a) of the Reactor Protection System trip setpoint table (Table 1) in Attachment 2.

Section 2.2 Page 2 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.1 AVERAGE POWER RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION (continued)

TESTING REQUIREMENTS 4.2.1.1 Deleted.

4.2.1.2 Perform a CHANNEL FUNCTIONAL TEST every 92 days for the following trip functions:

a. Flow-Biased Upscale

b. Inoperative

c. Downscale

d. Upscale, Startup 4.2.1.3 Perform a CHANNEL CALIBRATION, except for neutron detectors, every 184 days for the following trip functions:

a. Flow-Biased Upscale

b. N/A

c. Downscale

d. Upscale, Startup BASES 5.2.1 The control rod block functions are provided consistent with the requirements of Technical Specifications 3.3.2.1, Control Rod Block Instrumentation and 3.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip in the safety analyses. The Trip Setpoint and Allowable Value also contain additional margin for instrument accuracy and calibration.

Section 2.2 Page 3 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.2 SOURCE RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION OPERATIONAL REQUIREMENT The Source Range Monitoring (SRM) control rod block instrumentation channels in Table 2.2.2-1 shall be OPERABLE with their trip setpoints set consistent with the values specified in Table 3.2.2-1.

APPLICABILITY TABLE 2.2.2-1 SRM APPLICABILITY MINIMUM OPERABLE CHANNELS PER TRIP TRIP FUNCTION FUNCTION(e) APPLICABLE MODES

a. Detector not full in (a) 3 2#

b. Upscale (b) 3 2#

c. Inoperative (b) 3 2#

d. Downscale (c) 3 2#

With IRMs on range 2 or below.

(a) This function shall be automatically bypassed if detector count rate is > 100 cps or the IRM channels are on range 3 or higher.

(b) This function shall be automatically bypassed when the associated IRM channels are on range 8 or higher.

(c) This function shall be automatically bypassed when the IRM channels are on range 3 or higher.

(e) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided at least one other OPERABLE channel in the same trip function is monitoring that parameter.

Section 2.2 Page 4 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.2 SOURCE RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION (continued)

ACTIONS 3.2.2 With the number of OPERABLE Channels:

a. One less than required by the minimum OPERABLE channels per trip function requirement, restore the inoperable channel to OPERABLE status within 7 days or place the inoperable channel in the tripped condition within the next hour.

b. Two or more less than required by the minimum OPERABLE channels per trip function requirement, place at least one inoperable channel in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

TABLE 3.2.2-1 SOURCE RANGE MONITORS TRIP SETPOINTS TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE

a. Detector not full in N/A N/A

b. Upscale < 1 x 105 cps < 1.6 x 105 cps

c. Inoperative N/A N/A

d. Downscale > 3 cps > 1.8 cps TESTING REQUIREMENTS 4.2.2.1 Perform a CHANNEL FUNCTIONAL TEST every 31 days for the following trip functions:

a. Detector not full in

b. Upscale

c. Inoperative

d. Downscale Section 2.2 Page 5 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.2 SOURCE RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION (continued) 4.2.2.2 Perform a CHANNEL CALIBRATION, except neutron detectors, every 24 months for the following trip functions:

a. N/A

b. Upscale

c. N/A

d. Downscale 4.2.2.3 The provisions of Testing Requirement 1.3.4 are not applicable to the Source Range Monitor Testing requirements for entry into MODE 2# from MODE 1, provided the testing requirements are performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2#.

BASES 5.2.2 The control rod block functions are provided consistent with the requirements of Technical Specification 3.3.2.1, Control Rod Block Instrumentation and 3.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip in the safety analyses. The Trip Setpoint and Allowable Value also contain additional margin for instrument accuracy and calibration.

Section 2.2 Page 6 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.3 INTERMEDIATE RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION OPERATIONAL REQUIREMENT The Intermediate Range Monitoring (IRM) control rod block instrumentation channels in Table 2.2.3-1 shall be OPERABLE with their trip setpoints set consistent with the values specified in Table 3.2.3-1.

APPLICABILITY TABLE 2.2.3-1 IRM APPLICABILITY MINIMUM OPERABLE CHANNELS PER TRIP TRIP FUNCTION FUNCTION(e) APPLICABLE MODES

a. Detector not full in 6 2

b. Upscale 6 2

c. Inoperative 6 2

d. Downscale (d) 6 2 (d) This function shall be automatically bypassed when the IRM channels are on range 1.

(e) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided at least one other OPERABLE channel in the same trip function is monitoring that parameter.

ACTIONS 3.2.3 With the number of OPERABLE Channels:

a. One less than required by the minimum OPERABLE channels per trip function requirement, restore the inoperable channel to OPERABLE status within 7 days or place the inoperable channel in the tripped condition within the next hour.

b. Two or more less than required by the minimum OPERABLE channels per trip function requirement, place at least one inoperable channel in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Section 2.2 Page 7 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.3 INTERMEDIATE RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION (continued)

TABLE 3.2.3-1 INTERMEDIATE RANGE MONITORING TRIP SETPOINTS TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE

a. Detector not full in NA NA

b. Upscale < 108/125 full scale < 110/125 full scale

c. Inoperative NA NA

d. Downscale > 5/125 full scale > 3/125 full scale TESTING REQUIREMENTS 4.2.3.1 Perform a CHANNEL FUNCTIONAL TEST every 31 days for the following trip functions:

a. Detector Not Full In

b. Upscale

c. Inoperative

d. Downscale 4.2.3.2 Perform a CHANNEL CALIBRATION, except neutron detectors, every 24 months for the following trip functions:

a. N/A

b. Upscale

c. N/A d Downscale 4.2.3.3 The provisions of Testing Requirement 1.3.4 are not applicable to the Intermediate Range Monitor Testing Requirements for entry into MODE 2, from MODE 1, provided the Testing Requirements are performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

BASES 5.2.3 The control rod block functions are provided consistent with the requirements of Technical Specifications 3.3.2.1, Control Rod Block Instrumentation and 3.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.

Section 2.2 Page 8 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.3 INTERMEDIATE RANGE MONITORS - CONTROL ROD BLOCK INSTRUMENTATION (continued)

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip in the safety analyses. The Trip Setpoint and Allowable Value also contain additional margin for instrument accuracy and calibration.

Section 2.2 Page 9 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.4 SCRAM DISCHARGE VOLUME - CONTROL ROD BLOCK INSTRUMENTATION OPERATIONAL REQUIREMENT The Scram Discharge Volume (SDV) control rod block instrumentation channels in Table 2.2.4-1 shall be OPERABLE with their trip setpoints set consistent with the values specified in Table 3.2.4-1.

APPLICABILITY TABLE 2.2.4-1 SCRAM DISCHARGE VOLUME APPLICABILITY MINIMUM OPERABLE CHANNELS PER TRIP TRIP FUNCTION FUNCTION(e) APPLICABLE MODES

a. Water Level - High 2 1, 2 (e) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided at least one other OPERABLE channel in the same trip function is monitoring that parameter.

ACTION 3.2.4 With the number of OPERABLE channels less than required by the minimum OPERABLE channels per trip function requirement, verify within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months that a sufficient number of channels remain OPERABLE to initiate a rod block by the associated trip function, and place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, initiate a rod block.

Section 2.2 Page 10 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.4 SCRAM DISCHARGE VOLUME - CONTROL ROD BLOCK INSTRUMENTATION (continued)

TABLE 3.2.4-1 SCRAM DISCHARGE VOLUME TRIP SETPOINTS TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE

a. Water Level-High, < 12"# < 19 7/8"#

C11-N602A

b. Water Level-High, < 12"## < 19 7/8"##

C11-N602B

Instrument zero is 758' 5" msl.

1. Instrument zero is 758' 4 1/2" msl.

TESTING REQUIREMENTS 4.2.4.1 Perform a CHANNEL CHECK on the instruments listed in Table 2.2.4-1 every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.2.4.2 Perform a CHANNEL FUNCTIONAL TEST on the instruments listed in Table 2.2.4-1 every 92 days.

4.2.4.3 Perform a CHANNEL CALIBRATION on the instruments listed in Table 4.2.4-1 every 92 days for the Analog Trip Module.

4.2.4.4 Perform a CHANNEL CALIBRATION on the instruments listed in Table 2.2.4-1 every 24 months.

BASES 5.2.4 The control rod block functions are provided consistent with the requirements of Technical Specifications 3.3.2.1, Control Rod Block Instrumentation, and 3.2, Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip in the safety analyses. The Trip Setpoint and Allowable Value also contain additional margin for instrument accuracy and calibration.

Section 2.2 Page 11 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.5 REACTOR COOLANT SYSTEM RECIRCULATION FLOW -

CONTROL ROD BLOCK INSTRUMENTATION OPERATIONAL REQUIREMENT The Reactor Coolant System Recirculation Flow control rod block instrumentation channels in Table 2.2.5-1 shall be OPERABLE with their trip setpoints set consistent with the values specified in Table 3.2.5-1.

APPLICABILITY TABLE 2.2.5-1 REACTOR RECIRCULATION FLOW ROD BLOCK APPLICABILITY MINIMUM OPERABLE CHANNELS PER TRIP TRIP FUNCTION FUNCTION(e) APPLICABLE MODES

a. Upscale 3 1 (e) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided at least one other OPERABLE channel in the same trip function is monitoring that parameter.

ACTION 3.2.5 With the number of OPERABLE channels less than required by the minimum OPERABLE channels per trip function requirement, verify within one hour that a sufficient number of channels remain OPERABLE to initiate a rod block by the associated trip function, and place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, initiate a rod block.

TABLE 3.2.5-1 REACTOR RECIRCULATION FLOW ROD BLOCK TRIP SETPOINTS TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE

a. Upscale < 113 % of rated flow < 116 % of rated flow Section 2.2 Page 12 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.5 REACTOR COOLANT SYSTEM RECIRCULATION FLOW - CONTROL ROD BLOCK INSTRUMENTATION (continued)

TESTING REQUIREMENTS 4.2.5.1 Deleted.

4.2.5.2 Perform a CHANNEL FUNCTIONAL TEST on the instruments listed in Table 2.2.5-1 every 92 days.

4.2.5.3 Perform a CHANNEL CALIBRATION on the instruments listed in Table 2.2.5-1 every 184 days.

BASES 5.2.5 The control rod block functions are provided consistent with the requirements of Technical Specifications 3.3.2.1, Control Rod Block Instrumentation, and 3.2, Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip in the safety analyses. The Trip Setpoint and Allowable Value also contain additional margin for instrument accuracy and calibration.

Section 2.2 Page 13 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.6 AREA RADIATION MONITORING INSTRUMENTATION OPERATIONAL REQUIREMENT The Area Radiation Monitoring Instrumentation in Table 2.2.6-1 shall be OPERABLE with their alarm/trip setpoints set consistent with the values specified in Table 2.2.6-1.

APPLICABILITY TABLE 2.2.6-1 AREA RADIATION MONITORING APPLICABILITY MINIMUM APPLICABLE ALARM/TRIP INSTRUMENTATION CHANNELS MODES SETPOINT OPERABLE Area Monitors

a. New Fuel Storage Vault 1 # < 2.5 mR/hr**

b. Spent Fuel Storage Pool 1 ## < 2.5 mR/hr**

c. Control Room Direct 1 At all times < 2.5 mR/hr**

Radiation Monitor

- Alarm only.

With fuel in the new storage vault.

1. With irradiated fuel in the spent fuel storage pool.

ACTION:

3.2.6.1 With a radiation monitoring instrumentation channel alarm/trip setpoint exceeding the value shown in Table 2.2.6-1, adjust the setpoint to within the limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

3.2.6.2 With the required monitor inoperable, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

3.2.6.3 The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

Section 2.2 Page 14 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.6 AREA RADIATION MONITORING INSTRUMENTATION (continued)

TESTING REQUIREMENTS 4.2.6.1 Perform a CHANNEL CHECK on the instruments listed in Table 2.2.6-1 every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.2.6.2 Perform a CHANNEL FUNCTIONAL TEST on the instruments listed in Table 2.2.6-1 every 31 days.

4.2.6.3 Perform a CHANNEL CALIBRATION on the instruments listed in Table 2.2.6-1 every 24 months.

BASES 5.2.6 The OPERABILITY of the radiation monitoring instrumentation ensures that:

(1) the radiation levels are continually measured in the areas served by the individual channels; (2) the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded; and (3) sufficient information is available on selected plant parameters to monitor and assess these variables following an accident.

This capability is consistent with 10 CFR Part 50, Appendix A, General Design Criteria 19, 60, 61, 63 and 64.

Section 2.2 Page 15 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.7 SEISMIC MONITORING INSTRUMENTATION OPERATIONAL REQUIREMENTS The seismic monitoring instrumentation shown in Table 3.2.7-1 shall be OPERABLE.

APPLICABILITY At all times ACTION 3.2.7

a. With one or more of the above required seismic monitoring instruments inoperable for more than 30 days, initiate a Condition Report.

b. The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

TESTING REQUIREMENTS 4.2.7.1 Perform a CHANNEL FUNCTIONAL TEST for each of the required seismic monitoring instruments at the frequencies shown in Table 4.2.7-1.

4.2.7.2 Perform a CHANNEL CALIBRATION for each of the required seismic monitoring instruments at the frequencies shown in Table 4.2.7-1.

4.2.7.3 Each of the above required seismic monitoring instruments actuated during a seismic event > 0.02g shall be restored to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and a CHANNEL CALIBRATION performed within 5 days following the seismic event. Data shall be retrieved from actuated instruments and analyzed to determine the magnitude of the vibratory ground motion. A Condition Report shall be initiated describing the magnitude, frequency spectrum and resultant effect upon unit features important to safety.

Section 2.2 Page 16 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.7 SEISMIC MONITORING INSTRUMENTATION (continued)

TABLE 3.2.7-1 SEISMIC MONITORING INSTRUMENTATION MEASUREMENT RANGE INSTRUMENTS/LOCATIONS FREQUENCY FULL SCALE DYNAMIC MINIMUM RANGE (HZ) SENSITIVITY RANGE INSTRUMENT (g) ZERO TO S OPERABLE PEAK

1. Triaxial Accelerometers

a. Concrete pad (outside) El. 1 to 30 +/-2 100:1 l(c) 740' 10"

b. Aux. Bldg., El. 712' 1 to 30 +/-2 100:1 l(a)(c)

c. Containment Bldg., El. 851 1 to 30 +/-2 100:1 l(a)(c)

d. Control Bldg., El. 737' 1 to 30 +/-2 100:1 l(a)(c)

e. Containment(drywell wall), 1 to 30 +/-2 100:1 l(a)(c)

E1.779'-10"

2. Triaxial Peak Accelerographs (Passive)

a. Aux. Bldg., El. 718' 0 to 30 +/-5 20:1 1

b. DG Bldg., El. 729' 0 to 30 +/-5 20:1 1

c. Containment Bldg., El. 791' 0 to 30 +/-5 20:1 1

3. Triaxial Seismic Switches Aux. Bldg., El. 712' 0.1 to 30 +/-0.2 40:1 1(a)(b)

4. Recorders

a. Circulating Water Screen House 2 to 25 NA NA 1 (Passive Triaxial Response Spectrum Recorder)

b. Main Control Room Central Recording Unit 1 to 30 NA NA 1

5. Seismic Data Analyzer Main Control Room 1 to 30 NA NA 1 (a) With main control room annunciation.

(b) Adjustable setpoint (c) Accelerometer provides input to the Central Recording Unit.

Section 2.2 Page 17 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.7 SEISMIC MONITORING INSTRUMENTATION (continued)

TABLE 4.2.7-1 SEISMIC MONITORING TESTING FREQUENCIES CHANNEL FUNCTIONAL CHANNEL CALIBRATION INSTRUMENTS/LOCATIONS TEST 1 . Triaxial Accelerometers

a. Concrete pad (outside), El. 740' 10" 31 days 24 months

b. Aux. Bldg.,El. 712' 31 days 24 months

c. Containment Bldg., El. 851' 31 days 24 months

d. Control Bldg., El. 737' 31 days 24 months

e. Containment (drywell wall) El. 31 days 24 months 779'- 10"

2. Triaxial Peak Accelerographs (Passive)

a. Aux Bldg., El. 718' NA 24 months

b. DG Bldg., El. 729' NA 24 months

c. Containment Bldg., El. 791' NA 24 months

3. Triaxial Seismic Switches Aux. Bldg., El. 712' 31 days 24 months

4. Recorders

a. Circulating Water Screen House NA 24 months (Passive Triaxial Response Spectrum Recorder)

b. Main Control Room Central NA 24 months Recording Unit

5. Seismic Data Analyzer Main Control Room 31 days 24 months Section 2.2 Page 18 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.7 SEISMIC MONITORING INSTRUMENTATION (continued)

BASES 5.2.7 The OPERABILITY of the seismic monitoring instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured response to that used in the design basis for the unit. This instrumentation is consistent with the recommendations of Regulatory Guide 1.12 "Instrumentation for Earthquakes", April 1974.

Section 2.2 Page 19 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.8 METEOROLOGICAL MONITORING INSTRUMENTATION OPERATIONAL REQUIREMENTS The meteorological monitoring instrumentation channels shown in Table 3.2.8-1 shall be OPERABLE.

APPLICABILITY At all times ACTION 3.2.8

a. With one or more meteorological monitoring instrumentation channels inoperable for more than 7 days, initiate a Condition Report.

b. The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

TABLE 3.2.8-1 METEOROLOGICAL MONITORING INSTRUMENTATION INSTRUMENT MINIMUM INSTRUMENTS OPERABLE

1. Wind Speed

a. El. 768' 1

b. El. 932' 1

2. Wind Direction

a. El. 768' 1

b. El. 932' 1

3. Air Temperature Difference El. 768'/932' 1 Section 2.2 Page 20 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.8 METEOROLOGICAL MONITORING INSTRUMENTATION (continued)

TESTING REQUIREMENTS 4.2.8.1 Perform a CHANNEL CHECK every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for each of the meteorological monitoring instrumentation channels shown in Table 3.2.8-1.

4.2.8.2 Perform a CHANNEL CALIBRATION every 184 days for each of the meteorological monitoring instrumentation channels shown in Table 3.2.8-1.

BASES 5.2.8 The OPERABILITY of the meteorological monitoring instrumentation ensures that sufficient meteorological data is available for estimating potential radiation doses to the public as a result of routine or accidental release of radioactive materials to the atmosphere. This capability is required to evaluate the need for initiating protective measures to protect the health and safety of the public. This instrumentation is consistent with the recommendations of Regulatory Guide 1.23 "Onsite Meteorological Programs," with exceptions as noted in the Project Position on Regulatory Guide 1.23 in Subsection l.8 of the CPS USAR.

Section 2.2 Page 21 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.9 TRAVERSING IN-CORE PROBE SYSTEM OPERATIONAL REQUIREMENTS The traversing in-core probe system shall be OPERABLE with:

a. Three movable detectors, drives and readout equipment to map the core, and

b. Indexing equipment to allow three detectors to be calibrated in a common location.

APPLICABILITY When the traversing in-core probe is used for:

a. Recalibration of the LPRM detectors, and

b. Monitoring the APLHGR, LHGR, or MCPR.*

Only the detector(s) in the location(s) of interest are required to be OPERABLE.

ACTION 3.2.9 With the traversing in-core probe system inoperable, do not use the system for the above applicable monitoring or calibration functions. The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

TESTING REQUIREMENTS 4.2.9.1 The traversing in-core probe system shall be demonstrated OPERABLE by normalizing each of the above required detector outputs within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months prior to use when required for the LPRM or calibration functions.

BASES 5.2.9 The OPERABILITY of the traversing in-core probe (TIP) system with the specified, minimum complement of equipment ensures that the measurements obtained from use of this equipment accurately represent the spatial neutron flux distribution of the reactor core. The 3D MONICORE system is capable of adapting its calculation with sufficient accuracy with one TIP out-of-service, therefore only 3 of the 4 detectors are required to be operable for a full core monitoring or calibration.

Section 2.2 Page 22 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.9 TRAVERSING IN-CORE PROBE SYSTEM (continued)

The TIP system OPERABILITY is demonstrated by normalizing all required probes (i.e., detectors) prior to performing an LPRM calibration function. Monitoring core thermal limits may involve utilizing individual detectors to monitor selected areas of the reactor core, thus all detectors may not be required to be OPERABLE. The operability of individual detectors to be used for monitoring is demonstrated by comparing the detector(s) output with data obtained during the previous LPRM calibrations.

Section 2.2 Page 23 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.10 Deleted Section 2.2 Page 24 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.11 MAIN CONDENSER OFFGAS TREATMENT SYSTEM EXPLOSIVE GAS MONITORING INSTRUMENTATION OPERATIONAL REQUIREMENTS At least one main condenser offgas treatment system explosive gas monitoring instrumentation channel shall be OPERABLE with its alarm/trip setpoint set to ensure that the concentration of hydrogen in the main condenser offgas treatment system will not exceed 4% by volume.

APPLICABILITY During operation of the main condenser air ejector.

ACTION 3.2.11

a. With the explosive gas monitoring instrumentation channel alarm/trip setpoint less conservative than 4%, declare the channel inoperable and take the ACTION required below.

b. With less than 1 explosive gas monitoring instrumentation channel OPERABLE, operation of the main condenser offgas treatment system may continue provided grab samples are collected at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and analyzed within the following 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Restore the inoperable channel to OPERABLE status within 30 days and, if unsuccessful, initiate a Condition Report.

TESTING REQUIREMENTS 4.2.11.1 Perform a CHANNEL CHECK of the main condenser offgas treatment system explosive gas monitoring instrumentation every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4.2.11.2 Perform a CHANNEL FUNCTIONAL TEST of the main condenser offgas treatment system explosive gas monitoring instrumentation every 31 days.

4.2.11.3 Perform a CHANNEL CALIBRATION* of the main condenser offgas treatment system explosive gas monitoring instrumentation every 92 days.

The CHANNEL CALIBRATION shall include the use of standard samples containing a nominal,

1. 1.0 vol. % hydrogen, balance nitrogen, and

2. 4.0 vol. % hydrogen, balance nitrogen.

Section 2.2 Page 25 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.11 MAIN CONDENSER OFFGAS TREATMENT SYSTEM EXPLOSIVE GAS MONITORING INSTRUMENTATION (continued)

BASES 5.2.11 The main condenser offgas treatment system explosive gas monitoring instrumentation is provided to monitor and control the concentrations of potentially explosive gas mixtures in the main condenser offgas treatment system.

The intent of the

note attached to the CHANNEL CALIBRATION requirement is to specify that the CHANNEL CALIBRATION is to be performed using at least two separate gas samples of different, specific hydrogen concentrations appropriate for the sensor range. The balance of the sample gas mixture (normally nitrogen) is not necessarily restricted purely to nitrogen but must be in accordance with the requirements or recommendations provided by the manufacturer of the explosive gas monitoring instrumentation.

Section 2.2 Page 26 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.12 FEEDWATER SYSTEM/MAIN TURBINE TRIP OPERATIONAL REQUIREMENT The feedwater/main turbine trip Function shall have 3 channels of reactor vessel water level -

high, level 8, instrumentation OPERABLE.

APPLICABILITY Mode 1 ACTION 3.2.12

a. With one or more required channel(s) inoperable, restore channel(s) to an OPERABLE status within 7 days.

b. With the feedwater/main turbine trip Function not maintained, restore feedwater/main turbine trip capability within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

c. With Action and Completion Time not met for 3.2.12.a or 3.2.12.b, enter General Operational Requirement 1.2.3.

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

A Channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the Channel in the tripped condition provided at least one other OPERABLE Channel is monitoring that parameter.

TESTING REQUIREMENTS 4.2.12.1 Perform a CHANNEL CHECK every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.2.12.2 Perform a CHANNEL FUNCTIONAL TEST every 184 days.

4.2.12.3 Perform a CHANNEL CALIBRATION every 24 months. The trip setpoint shall be 52.0 inches.

4.2.12.4 Perform a LOGIC SYSTEM FUNCTIONAL TEST every 24 months.

Section 2.2 Page 27 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

BASES 5.2.12 Trip function can be maintained by removing the affected component (feedwater pump(s) and/or main turbine) from service and administratively controlling the status in a tripped condition.

Section 2.2 Page 28 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.13 ADS ACCUMULATOR LOW PRESSURE ALARM SYSTEM INSTRUMENTATION OPERATIONAL REQUIREMENTS The ADS accumulator low pressure alarm system instrumentation shall be OPERABLE with an alarm setpoint of > 140 psig on decreasing pressure.

APPLICABILITY MODES 1, 2*, and 3*

Not required when reactor steam dome pressure is less than or equal to 150 psig ACTION 3.2.13.1 With an ADS accumulator low pressure alarm system instrumentation channel(s) inoperable:

a. Determine the associated ADS accumulator system pressure from alternate indication and verify that ADS accumulator pressure is greater than or equal to 140 psig at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

b. Restore the inoperable ADS accumulator low pressure alarm system instrumentation channel(s) to OPERABLE status within 30 days and, if unsuccessful, initiate a Condition Report.

c. The provisions of Operational Requirement 1.2.4 are not applicable.

TESTING REQUIREMENTS 4.2.13.1 At least once per 31 days, performing a CHANNEL FUNCTIONAL TEST of the accumulator low pressure alarm system.

4.2.13.2 At least once per 24 months, performing a CHANNEL CALIBRATION of the accumulator low pressure alarm system and verifying an alarm setpoint of

> 140 psig on decreasing pressure.

Section 2.2 Page 29 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.14 NSPS SELF TEST SYSTEM OPERATIONAL REQUIREMENTS The SELF TEST SYSTEM (STS) of the Nuclear System Protection System shall be OPERABLE and operating in the fully automatic mode.*

In lieu of continuous, fully automatic operation, the STS may be operated manually or in a partially automatic mode such that it performs all required tests at least once per 7 days during Modes 1, 2, and 3; or at least once per 90 days during Modes 4 and 5.

APPLICABILITY MODES 1, 2, 3, 4, and 5.

ACTION 3.2.14.1 With the STS not operating in the required mode, i.e., in the fully automatic mode or being operated in a manual or partially automatic mode such that all required tests are performed at least once per 7 days during Modes 1, 2, and 3; or at least once per 90 days during Modes 4 and 5.

a. In Modes 1, 2, and 3, restore the STS to the required mode within 30 days, and initiate a Condition Report.

b. In Modes 4 and 5, restore the STS to the required mode within 90 days or suspend CORE ALTERATIONS and operations with a potential for draining the reactor vessel, verify all insertable control rods to be fully inserted and lock the reactor mode switch in the Shutdown position within one hour.

3.2.14.2 The provisions of Operational Requirement 1.2.3 and 1.2.4 are not applicable.

Section 2.2 Page 30 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.14 NSPS SELF TEST SYSTEM (continued)

TESTING REQUIREMENTS 4.2.14.1 Status indications of the STS shall be obtained at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , whenever the STS is operating in the fully or partially automatic mode.

BASES 5.2.14 This specification provides the minimum requirements necessary to preserve the STS's ability to perform its intended function of detecting and determining the location of a fault in the functional NSPS.

The Self Test System (STS) is an overlay testing and surveillance subsystem which provides the capability to continuously and automatically perform testing of all active circuitry within the NSPS panels, essential to the safe shutdown of the reactor. The primary purpose of the STS is to enhance the availability of the NSPS by optimizing the time to detect and determine the location of a failure in the functional system. Each of the four NSPS cabinets, with one cabinet associated with each of the four Class IE powered NSPS divisions, contains its own controller. The STS may be used for post-maintenance testing and to augment conventional testing methods which include CHANNEL CHECKS, CHANNEL FUNCTIONAL TESTS, CHANNEL CALIBRATIONS, RESPONSE TIME TESTS and LOGIC SYSTEM FUNCTIONAL TESTS.

Under the provision of the ACTION statement, with the STS inoperable or not operating in the required mode of operation, 30 days is allowed to restore the STS to the required mode during MODES 1, 2, 3; 90 days is allowed during MODES 4, 5.

The Operational Requirement includes an allowance for manually operating the STS to perform testing equivalent to that which is normally performed during automatic operation. System operating characteristics allow the operator to determine that the STS is operating automatically or partially automatically. Manual or partially automatic STS testing is required to be performed at least once per 7 days during MODES 1, 2, 3 and at least once per 90 days during MODES 4, 5. These frequencies and allowed out-of-service times have been shown by analysis to be acceptable for supporting adequate overall availability of the NSPS (

Reference:

EAS-67-1089, "Proposed Improved Technical Specification for Clinton Nuclear Power Station Nuclear Systems Protection System (NSPS) Self Test System (STS)"). Maintaining the STS in a partially automatic mode as much as possible (whenever it is not operating in the fully automatic mode) provides further enhancement of the NSPS availability.

Section 2.2 Page 31 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.15 SUPPRESSION POOL WATER TEMPERATURE INDICATORS OPERATIONAL REQUIREMENT Sixteen suppression pool water temperature indicators, with at least two channels in each suppression pool sector, shall be OPERABLE with the high water temperature alarm set for <

93° F.

APPLICABILITY MODES 1, 2, and 3 ACTION 3.2.15.1 With fewer than 16 suppression pool water temperature indicators OPERABLE, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of indicator inoperability verify at least one temperature indicator OPERABLE in each of eight suppression pool sectors.

3.2.15.2 With no OPERABLE suppression pool water temperature indicator in one suppression pool sector, either restore at least one inoperable temperature indicator in each suppression pool sector to OPERABLE status within 7 days or verify suppression pool water temperature to be within limit at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

3.2.15.3 With no OPERABLE suppression pool water temperature indicator in two or more suppression pool sectors, restore at least one inoperable temperature indicator in at least seven suppression pool sectors to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

3.2.15.4 The provisions of Operational Requirement 1.2.3 are not applicable.

TESTING REQUIREMENTS 4.2.15.1 Perform a CHANNEL CHECK of the suppression pool water temperature indicators, at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4.2.15.2 Perform a CHANNEL FUNCTIONAL TEST of the suppression pool water temperature indicators, at least once per 31 days.

4.2.15.3 Perform a CHANNEL CALIBRATION of the suppression pool water temperature indicators, with the water high temperature alarm setpoint set for < 93° F, at least once per 24 months.

Section 2.2 Page 32 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.16 MAIN STEAM LINE RADIATION MONITORING (MSLRM)

INSTRUMENTATION OPERATIONAL REQUIREMENT The Main Steam Line Radiation Monitoring (MSLRM) Instrumentation shown in Table 3.2.16-1 shall be OPERABLE with their alarm/trip setpoints set consistent with the values specified in Table 3.2.16-1.

APPLICABILITY See Table 3.2.16-1 ACTIONS 3.2.16.1

a. With a MSLRM channel trip setpoint less conservative than the allowable value shown in Table 3.2.16-1, declare the channel inoperable until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value.

b. Restore the inoperable channel to OPERABLE within 30 days or initiate a Condition Report.

Table 3.2.16-1 MSLRM Instrumentation MINIMUM ALARM/ TRIP ALLOWABLE INSTRUMENTATION CHANNELS SETPOINT VALUE APPLICABILITY

1. MECHANICAL VACUUM PUMP

a. Main Steam Line 1 < 1.5 x full < 3.6 x full power Modes 1, 2, 3 Radiation-High power background #

background #

b. Main Steam Line 2 (a) 3.0 x full power < 6.0 x full power Modes 1, 2, 3 when Radiation-High High background background the mechanical vacuum pump is operating (b)

Alarm Setpoint.

(a) A channel may be placed in an inoperable status for required testing.

(b) Not isolated from main condenser.

Section 2.2 Page 33 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.16 MAIN STEAM LINE RADIATION MONITORING (MSLRM)

INSTRUMENTATION (continued)

TESTING REQUIREMENTS 4.2.16.1 Perform a CHANNEL CHECK every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for the MSLRM instrumentation.

4.2.16.2 Perform a CHANNEL FUNCTIONAL TEST every 92 days for the MSLRM instrumentation.

4.2.16.3 Perform a CHANNEL CALIBRATION every 24 months for the MSLRM instrumentation.

4.2.16.4 LOGIC SYSTEM FUNCTIONAL TESTS shall be performed at least once per 24 months.

BASES 5.2.16 The Main Steam Line Radiation (MSLR) High-High mechanical vacuum pump trip function is provided to detect a significant increase in the radiation levels in the main steam lines when the mechanical vacuum pump is aligned to the main condenser.

Isolation signals generated from the MSLRs are not credited for any design basis event.

The MSLR CRVICS isolation and RPS Scram functions were removed from the Technical Specifications based on the applicability of General Electric Topical Report NEDO-31400A, "Safety Evaluation for Eliminating the Boiling Water Reactor Main Steam Line Radiation Monitor," to CPS. This Topical Report provided the results of generic evaluations which indicated that the main steam line radiation monitors are unnecessary to ensure compliance with the radiation dose guidelines of 10 CFR 100.

With the elimination of the main steam line radiation monitor isolation function from the plant design the main control room alarm function and the automatic trip of the Mechanical Vacuum Pump are retained. The high radiation alarm alerts operators to consider other plant indications in determining the source of the increased radiation, such as the onset of leakage from a fuel pin(s). These actions will ensure that any significant increases in the levels of radioactivity in the main steam lines will be expeditiously controlled (by procedure) to limit both occupational doses and environmental releases.

Alarm and trip settings are established at a level away from the normal operating range to prevent inadvertent actuation of the systems involved. Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip. The Trip Setpoint and Allowable Value also contain additional margin for instrument accuracy and calibration capability. Two channels are required operable to provide mechanical vacuum pump trip capability. Either channel will initiate the MSL Radiation - High annunciator.

Section 2.2 Page 34 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.2.17 HYDROGEN MONITORING EQUIPMENT OPERATIONAL REQUIREMENTS One Channel of Primary Containment and Drywell Hydrogen Monitoring Equipment shall be OPERABLE.

APPLICABILITY MODES 1 and 2 ACTIONS 3.2.17 a. With the required channel inoperable, restore the required channel to an OPERABLE status within 7 days.

b. With Action and Completion Time of 3.2.17.a not met, initiate a Condition Report, and identify an alternate means of monitoring hydrogen.

TESTING REQUIREMENTS 4.2.17.1 Perform a CHANNEL CHECK every 31 days.

4.2.17.2 Perform a CHANNEL CALIBRATION every 92 days.

BASES 5.2.17 A hydrogen monitor is required to assess the degree of core damage during a beyond design-basis accident and confirm that random or deliberate ignition has taken place. If an explosive mixture that could threaten containment integrity exists during a beyond design-basis accident, then other severe accident management strategies, such as purging and/or venting, would need to be considered. A hydrogen monitor is needed to implement these severe accident management strategies. With the elimination of the design-basis LOCA hydrogen release, hydrogen monitor is no longer required to mitigate design-basis accidents and, therefore, the hydrogen monitor does not meet the definition of a safety-related component as defined in 10CFR50.2. The actions ensure that the regulatory commitment to maintain a hydrogen monitoring system capable of diagnosing beyond design-basis accidents is maintained.

Section 2.2 Page 35 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.3 REACTOR COOLANT SYSTEMS 2.3.1 REACTOR COOLANT SYSTEM CHEMISTRY OPERATIONAL REQUIREMENTS The chemistry of the reactor coolant system shall be maintained within the limits specified in the Table 3.3.1-1.

APPLICABILITY At all times.

ACTION 3.3.1.1 In MODE 1:

a. With the conductivity, chloride concentration, or pH exceeding the limit specified in Table 3.3.1-1 for less than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months during one continuous time interval and, for conductivity and chloride concentration, for less than 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months per year, but with the conductivity less than 10 micro mho/cm at 25°C and with the chloride concentration less than 0.5 ppm, this need not be reported to the Commission and the provisions of Operational Requirement 1.2.4 are not applicable.

b. With the conductivity, chloride concentration, or pH exceeding the limit specified in Table 3.3.1-1 for more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months during one continuous time interval or with the conductivity and chloride concentration exceeding the limit specified in Table 3.3.1-1, for more than 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months per year, be in at least MODE 2 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c. With the conductivity exceeding 10 micro mho/cm at 25°C or chloride concentration exceeding 0.5 ppm, be in at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in MODE 4 within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

3.3.1.2 In MODES 2 and 3 with the conductivity, chloride concentration or pH exceeding the limit specified in Table 3.3.1-1 for more than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months during one continuous time interval, be in at least MODE 3 within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in MODE 4 within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Section 2.3 Page 1 Rev. 65 April 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.3.1 REACTOR COOLANT SYSTEM CHEMISTRY (continued) 3.3.1.3 At all other times:

a. With the conductivity or pH exceeding the limit specified in Table 3.3.1-1, restore the conductivity and pH to within the limit within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the reactor coolant system. Determine that the structural integrity of the reactor coolant system remains acceptable for continued operation prior to proceeding to MODE 3.

b. With the chloride concentration exceeding the limit specified in Table 3.3.1-1 restore the chloride concentration to within the limit within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the reactor coolant system. Determine that the structural integrity of the reactor coolant system remains acceptable for continued operation prior to proceeding to MODE 3.

c. The provisions of Operational Requirement 1.2.3 are not applicable.

TESTING REQUIREMENTS 4.3.1.1 The reactor coolant conductivity and chlorides shall be determined to be within the specified chemistry limit by measurement prior to pressurizing the reactor during each reactor startup, if not performed within the previous 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

4.3.1.2 Reactor coolant samples shall be analyzed for chlorides at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and every 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months whenever conductivity is greater than the limit in Table 3.3.1-1.

4.3.1.3 Reactor coolant samples shall be analyzed for conductivity at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

4.3.1.4 Reactor coolant samples shall be analyzed for pH every 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months whenever conductivity is greater than the limit in Table 3.3.1-1.

Section 2.3 Page 2 Rev. 65 April 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.3.1 REACTOR COOLANT SYSTEM CHEMISTRY (continued) 4.3.1.5 Reactor coolant conductivity shall be continuously recorded. If the continuous recording conductivity monitor is inoperable, obtain in-line conductivity measurements, or a dip sample from the fuel pool, every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months in MODES 1, 2 and 3, and every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months at all other times.

4.3.1.6 Perform a CHANNEL CHECK of the continuous conductivity monitor with an in-line flow cell every 7 days, and every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when the conductivity is greater than the limit in Table 3.3.1-1.

Table 3.3.1-1 REACTOR COOLANT SYSTEM CHEMISTRY LIMITS CONDUCTIVITY MODE CHLORIDES pH

(µmhos/cm @ 25°C) 1 < 0.2 ppm < 1.0 5.6 < pH < 8.6 2 and 3 < 0.1 ppm < 2.0 5.6 < pH < 8.6 At all other times < 0.5 ppm < 10.0 5.3 < pH < 8.6 BASES 5.3.1 The water chemistry limits of the reactor coolant system are established to prevent damage to the reactor materials in contact with the coolant. Chloride limits are specified to prevent stress corrosion cracking of the stainless steel.

The effect of chloride is not as great when the oxygen concentration in the coolant is low, thus the 0.2 ppm limit on chlorides is permitted during POWER OPERATION.

During shutdown and refueling operations, the temperature necessary for stress corrosion to occur is not present so a 0.5 ppm concentration of chlorides is not considered harmful during these periods.

Conductivity measurements are required on a continuous basis since changes in this parameter are an indication of abnormal conditions. When the conductivity is within limits, the pH, chlorides and other impurities affecting conductivity must also be within their acceptable limits. With the conductivity meter inoperable, additional samples must be analyzed to ensure that the chlorides are not exceeding the limits.

The testing requirements provide adequate assurance that concentrations in excess of the limits will be detected in sufficient time to take corrective action.

During outage refueling with no available means to obtain an in-line conductivity measurement, dip sample conductivity may be obtained from the fuel pool when the reactor vessel head is removed and the reactor cavity is flooded.

Section 2.3 Page 3 Rev. 65 April 2009

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4. PLANT SYSTEMS 2.4.1 SNUBBERS OPERATIONAL REQUIREMENTS All required snubbersshall be OPERABLE. Not applicable to snubbers installed on non-safety related systems and then only if their failure or failure of the system on which they are installed would have no adverse effect on any safety-related system. (Non-ISI snubbers)

APPLICABILITY MODES 1, 2, and 3.

MODES 4 and 5 for snubbers located on systems required OPERABLE in those MODES.

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

Separate Condition entry is allowed for each snubber.

ACTION 3.4.1 With one or more required snubbers removed or inoperable:

a. Immediately determine if attached system is OPERABLE.

b. Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , replace or restore the inoperable snubber(s) to OPERABLE status.

AND

c. Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , perform an engineering evaluation on the components to which the inoperable snubbers are attached. The purpose of this engineering evaluation shall be to determine if the components to which the inoperable snubbers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed service.

d. Required Actions and associated Completion Times of 3.4.1.a, 3.4.1.b. and 3.4.1.c not met, immediately declare the attached system inoperable and follow the appropriate Required Actions for that system.

3.4.2 An engineering evaluation shall be made of each failure to meet the functional test acceptance criteria to determine the cause of the failure. The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the OPERABILITY of other snubbers irrespective of type, which may be subject to the same failure mode.

Section 2.4 Page 1 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.1 SNUBBERS (continued)

If any snubber selected for functional testing either fails to lock up or fails to move, i.e.,

frozen-in-place, the cause will be evaluated and if caused by manufacturer or design deficiency all snubbers of the same type subject to the same defect shall be functionally tested. This testing requirement shall be independent of the requirements stated in Testing Requirement 4.4.1.e for snubbers not meeting the functional test acceptance criteria.

4.4.1 Each required snubber shall be demonstrated OPERABLE by the performance of the following inservice inspection program in addition to the requirements of Operational Requirement 1.3.5.

a. Visual Inspections For the purpose of Visual Inspections Snubbers are categorized as inaccessible or accessible during reactor operation. Each of these categories (inaccessible and accessible) may be inspected independently according to the schedule determined by the Inservice Inspection Program Plan.

b. Visual Inspection Acceptance Criteria Visual inspections shall verify that (1) the snubber has no visible indications of damage or impaired OPERABILITY, (2) attachments to the foundation or supporting structure are functional, and (3) fasteners for the attachment of the snubber to the component and to the snubber anchorage are functional. Snubbers which appear inoperable as a result of visual inspections shall be classified as unacceptable and may be reclassified acceptable for the purpose of establishing the next visual inspection interval, provided that: (1) the cause of the rejection is clearly established and remedied for that particular snubber and for other snubbers, irrespective of type, that may be generically susceptible; and (2) the affected snubber is functionally tested in the as-found condition and determined OPERABLE per Testing Requirement 4.4.1.f. All snubbers found connected to an inoperable common hydraulic fluid reservoir shall be counted as unacceptable for determining the next inspection interval. A review and evaluation shall be performed and documented to justify continued operation with an unacceptable snubber. If continued operation cannot be justified, the snubber shall be declared inoperable and the ACTION requirements shall be met.

c. Transient Event Inspection An inspection shall be performed of all required snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients, as determined from a review of operational data or a visual inspection of the systems, within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for accessible areas and within 6 months for inaccessible areas following this determination. In addition to satisfying the visual inspection Section 2.4 Page 2 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.1 SNUBBERS (continued) acceptance criteria, freedom-of-motion of mechanical snubbers shall be verified using at least one of the following: (1) manually induced snubber movement; or (2) evaluation of in-place snubber piston setting; or (3) stroking the mechanical snubber through its full range of travel.

d. Functional Tests For the purpose of Functional Testing Snubbers, Defined Test Plan Groups (DTPGs) may be per the Inservice Inspection Program Plan. At least once per refueling outage, a representative sample of snubbers shall be tested using one of the sample plans identified in the ISI Program Plan for each DTPG. The sample plan shall be selected prior to the test period and cannot be changed during the test period. The NRC Regional Administrator shall be notified in writing of the sample plan selected prior to the test period or the sample plan used in the prior test period shall be implemented.

e. Functional Test Acceptance Criteria The snubber functional test shall verify that:

1. Activation (restraining action) is achieved within the specified range in both tension and compression;

2. Snubber bleed, or release rate where required, is present in both tension and compression, within the specified range;

3. For mechanical snubbers, the force required to initiate or maintain motion of the snubber is within the specified range in both directions of travel; and

4. For snubbers specifically required not to displace under continuous load, the ability of the snubber to withstand load without displacement.

Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.

f. Functional Testing of Repaired and Replaced Snubbers Snubbers that fail the visual inspection or the functional test acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers that have repairs that might affect the functional test result shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom-of-motion test must have been performed within 12 months before being installed in the unit.

Section 2.4 Page 3 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.1 SNUBBERS (continued) 5.4.1 All required snubbers are required OPERABLE to ensure that the structural integrity of the reactor coolant system and all other safety related systems is maintained during and following a seismic or other event initiating dynamic loads.

For the purpose of Functional Testing, snubbers may be classified in accordance with ASME OM Code, Subsection ISTD. Snubbers may be classified as one population, or divided into the two categories of accessible and inaccessible, or grouped by design, manufacturer, size and type. For example, mechanical snubbers utilizing the same design features of the 2-kip, 10-kip, and 100-kip capacity manufactured by Company "A" are of the same type. The same design mechanical snubbers manufactured by Company "B" for the purposes of this Technical Specification would be of a different type, as would hydraulic snubbers from either Manufacturer.

When a required snubber is found inoperable, an engineering evaluation is performed, in addition to the determination of the snubber mode of failure, in order to determine if any safety-related component or system has been adversely affected by the inoperability of the snubber. The engineering evaluation shall determine whether or not the snubber mode of failure has imparted a significant effect or degradation on the supported component or system.

A representative sample of the installed snubbers will be functionally tested to establish operational readiness at least once per refueling interval. Observed failures of these sample snubbers will require functional testing of additional units. To provide further assurance of snubber operability, snubbers are examined at the frequencies required in the ASME OM Code, Subsection ISTD and applicable Code Cases.

Hydraulic snubbers and mechanical snubbers may each be treated as a different entity for the above surveillance programs. The service life of a snubber is evaluated via manufacturer input and information through consideration of the snubber service conditions and associated installation and maintenance records, i.e., newly installed snubber, seal replaced, spring replaced, in high radiation area, in high temperature area, etc. The requirement to monitor the snubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions. These records will provide statistical bases for future consideration of snubber service life. The requirements for the maintenance of records and the snubber service life review are not intended to affect plant operation.

Section 2.4 Page 4 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.2 SEALED SOURCE CONTAMINATION OPERATIONAL REQUIREMENTS Each sealed source containing radioactive material either in excess of 100 microcuries of beta and/or gamma emitting material or 10 microcuries of alpha emitting material shall be free of greater than or equal to 0.005 microcuries of removable contamination.

The isotope segments of the GE 14i Isotope Test Assembly program contain double encapsulated cobalt targets that have characteristics similar to the description of a sealed source. These isotope segments are not a sealed source and are not subject to the requirements of this section.

APPLICABILITY At all times.

ACTION 3.4.2

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

1. Decontaminate and repair the sealed source, or

2. Dispose of the sealed source in accordance with Commission Regulations.

b. The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

TESTING REQUIREMENTS 4.4.2.1 Test Requirements - Each sealed source shall be tested for leakage and/or contamination by:

a. The licensee, or

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

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

4.4.2.2 Test Frequencies - Each category of sealed sources, excluding startup sources and fission detectors previously subjected to core flux, shall be tested at the frequency described below.

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

1. With a half-life greater that 30 days, excluding Hydrogen 3, and

2. In any form other than gas.

Section 2.4 Page 5 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.2 SEALED SOURCE CONTAMINATION (continued)

b. Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous six months. Sealed sources and fission detectors transferred without a certificate indicating the last test date shall be tested prior to being placed into use.

c. Startup sources and fission detectors - Each sealed startup source and fission detector shall be tested within 31 days prior to being subjected to core flux or installed in the core and following repair or maintenance to the source.

4.4.2.3 Reports - A report shall be prepared and submitted to the Commission on an annual basis if sealed source or fission detector leakage tests reveal the presence of greater than or equal to 0.005 microcuries of removable contamination.

BASES 5.4.2 The limitations on removable contamination for sources requiring leak testing, including alpha emitters, is based on 10 CFR 70.39(c) limits for plutonium. This limitation will ensure that leakage from byproduct, source, and special nuclear material sources will not exceed allowable intake values. Sealed sources are classified into three groups according to their use, with surveillance requirements commensurate with the probability of damage to a source in that group. Those sources which are frequently handled are required to be tested more often than those which are not. Sealed sources which are continuously enclosed within a shielded mechanism, i.e., sealed sources within radiation monitoring devices, are considered to be stored and need not be tested unless they are removed from the shielded mechanism.

Section 2.4 Page 6 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.4 LIQUID STORAGE TANKS OPERATIONAL REQUIREMENTS The quantity of radioactive material contained in each of the following unprotected outdoor tanks shall be limited to less than or equal to 10 curies, excluding tritium and dissolved or entrained noble gases.

a. Cycled Condensate Storage Tank

b. RCIC Storage Tank

c. Outside temporary tank.

APPLICABILITY At all times ACTION 3.4.4

a. With the quantity of radioactive material in any of the above listed tanks exceeding the above limit, immediately suspend all additions of radioactive material to the tank, within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tank contents to within the limit, and describe the events leading to this condition in the next Radioactive Effluent Release Report.

b. The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

TESTING REQUIREMENTS 4.4.4 The quantity of radioactive material contained in each of the above listed tanks shall be determined to be within the above limit by analyzing a representative sample of the tank's contents at least once per 7 days when radioactive materials are being added to the tank.

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

Section 2.4 Page 7 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.4 LIQUID STORAGE TANKS (continued)

BASES 5.4.4 The tanks listed in this section include all those outdoor storage tanks that are not surrounded by liners, dikes, or walls capable of holding the tank contents and that do not have tank overflows and surrounding area drains connected to the liquid radwaste treatment system.

Restricting the quantity of radioactive material contained in each of the specified tanks provides assurance that in the event of an uncontrolled release of the contents from any of these tanks, the resulting concentrations would be less than the limits of 10 CFR Part 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an UNRESTRICTED AREA.

Section 2.4 Page 8 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.5 MAIN CONDENSER OFFGAS HYDROGEN MONITORING OPERATIONAL REQUIREMENTS The concentration of hydrogen in the main condenser offgas treatment system shall be limited to less than or equal to 4% by volume.

APPLICABILITY Whenever the main condenser air ejector is in operation.

ACTION 3.4.5

a. With the concentration of hydrogen in the main condenser offgas treatment system exceeding the limit, restore the concentration to within the limit within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

b. The provisions of Operational Requirements 1.2.3 and 1.2.4 are not applicable.

TESTING REQUIREMENTS 4.4.5 The concentration of hydrogen in the main condenser offgas treatment system shall be determined to be within the above limits by continuously monitoring the waste gases in the main condenser offgas treatment system whenever the main condenser evacuation system is in operation with the hydrogen monitors required OPERABLE by Operational Requirement 2.2.11.

BASES 5.4.5 Although there should normally be more than sufficient steam flow to the steam jet air ejectors to ensure adequate dilution of hydrogen (and thus prevent the offgas from attaining hydrogen levels in excess of the flammability limit), this specification is provided to ensure that the concentration of potentially explosive gas mixtures contained in the offgas holdup system is monitored and maintained below the flammability limit of hydrogen. Maintaining the concentration of hydrogen below its flammability limit provides assurance that the releases of radioactive materials will be controlled in conformance with the requirements of General Design Criterion 60 of Appendix A to 10 CFR Part 50.

Section 2.4 Page 9 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.6 DRYWELL POST-LOCA VACUUM RELIEF VALVES OPERATIONAL REQUIREMENTS All drywell post-LOCA vacuum relief valves position indicators shall be OPERABLE.

APPLICABILITY MODES 1, 2, and 3.

ACTION 3.4.6 With the position indicator of one or more OPERABLE drywell post-LOCA vacuum relief valve(s) inoperable, verify at least one vacuum relief valve in each affected penetration to be closed** at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , and initiate a condition report.

The provisions of Operational Requirement 1.2.3 and 1.2.4 are not applicable.

- Drywell post-LOCA vacuum relief valves may be opened on an intermittent basis under administrative controls to perform required surveillance testing.

TESTING REQUIREMENTS 4.4.6.1 At least once per 31 days verify the position indicator OPERABLE by observing expected valve movement during the cycling test.

4.4.6.2 At least once per 24 months verify the position indicator OPERABLE by performance of a CHANNEL CALIBRATION.

Section 2.4 Page 10 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.8 SPENT FUEL STORAGE, CASK STORAGE AND UPPER CONTAINMENT POOLS OPERATIONAL REQUIREMENTS At least 23 feet of water shall be maintained over the top of irradiated fuel assemblies seated in the spent fuel storage, cask storage and upper containment fuel pool racks.

APPLICABILITY Whenever irradiated fuel assemblies are in the spent fuel storage, cask storage or upper containment fuel pools.

ACTION 3.4.8 With the above requirements not satisfied, suspend all movement of fuel assemblies and crane operations with loads in the spent fuel storage or upper containment fuel pool areas, as applicable after placing the fuel assemblies and crane load in a safe condition.

The provisions of Operational Requirement 1.2.3 are not applicable.

TESTING REQUIREMENTS 4.4.8 The water level in the spent fuel storage and upper containment fuel pools shall be determined to be at least at its minimum required depth at least once per 7 days.

BASES 5.4.8 The restrictions on minimum water level ensure that sufficient water depth is available to remove 99% of the assumed 10% iodine gap activity released from the rupture of an irradiated fuel assembly. This minimum water depth is consistent with the assumptions of the accident analysis.

With irradiated fuel assemblies in the cask storage pool, the gates between the cask storage pool and spent fuel pool must be open to ensure removal of decay heat from the cask storage pool. Thus, water level in the cask storage pool is monitored via the spent fuel pool level indication.

Section 2.4 Page 11 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.9 ESSENTIAL SWITCHGEAR ROOM (VX) VENTILATION OPERATIONAL REQUIREMENTS The temperature of the areas cooled by the Division 1, 2 and 3 essential switchgear heat removal (VX) system shall be maintained < 95 degrees F.

APPLICABILITY Whenever the equipment in the associated area is required to be OPERABLE.

ACTION 3.4.9.1 With an area temperature greater than 95 degrees F,

a. Perform TR 4.4.9.1 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter, and

b. Restore the area temperature to within the limit within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or place the safety related switchgear heat removal coil cabinet in service, if not already in service.

3.4.9.2 With an area temperature greater than 104 degrees F,

a. Immediately take action to restore the area temperatures within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , and

b. Declare the equipment in the affected area inoperable.

3.4.9.3 If Action 3.4.9.2 is entered, prepare a report in accordance with Operational Requirement 6.6.

TESTING REQUIREMENTS 4.4.9.1 Verify the temperature of the areas cooled by the VX system to be < 95 degrees F every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

BASES 5.4.9.1 The switchgear heat removal (VX) system is discussed in USAR Section 9.4.5.2. The VX system is designed to limit the maximum temperatures inside the switchgear rooms to 95 degrees F during normal plant operation and to 104 degrees F during abnormal plant operation in conformance with equipment ambient temperature ratings and requirements. However, cooling system equipment is sized to maintain a nominal room temperature of 95 degrees under normal and abnormal operating conditions. The VX system for each division consists of two independent switchgear heat removal coil cabinets, one safety-related and one non-safety related, connected to a common supply duct system. Each VX system coil cabinet consists of a filter, cooling coil, and fan.

The non-safety related VX system coil cabinet has a chilled water coil fed from the plant chilled water system and is utilized for cooling during normal station operating conditions only. The safety-related VX system coil cabinet is a standby and has a Section 2.4 Page 12 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.9 ESSENTIAL SWITCHGEAR ROOM (VX) VENTILATION (continued) refrigerant evaporator coil fed from a water-cooled condensing unit located within the switchgear room. This coil is to be utilized during abnormal operating conditions or upon failure of the chilled water VX system coil cabinets. The condenser heat is removed by shutdown service water or plant service water as discussed in USAR Subsections 9.2.1.2 and 9.2.1.1, respectively.

ORM 2.4.9 is applicable to the general areas of the essential switchgear rooms, and the equipment in these areas; however, ORM 2.4.9 is not directly applicable to the inverter rooms or the battery rooms. Refer to TS LCO 3.8.7 and 3.8.8 for the inverters and TS LCO 3.8.6 for the batteries.

Section 2.4 Page 13 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.4.10 PRIMARY CONTAINMENT HYDROGEN RECOMBINER OPERATIONAL REQUIREMENTS One Primary Containment Hydrogen Recombiner shall be OPERABLE.

APPLICABILITY When both divisions of hydrogen igniters are inoperable, requiring entry into TS 3.6.3.2, Condition B.

ACTION 3.4.10 With no hydrogen recombiner OPERABLE, immediately enter TS 3.6.3.2, Condition C.

TESTING REQUIREMENTS 4.4.10.1 Perform a FUNCTIONAL TEST for the hydrogen recombiner, every 24 months.

4.4.10.2 Visually examine the Primary Containment Hydrogen Recombiner enclosure and very there is no evidence of abnormal conditions, every 24 months.

4.4.10.3 Perform a resistance to ground test for each heater phase, every 24 months.

BASES 5.4.10.1 The revised 10CFR50.44 no longer defines a design-basis LOCA hydrogen release, and eliminated requirements for hydrogen control systems to mitigate such a release. The installation of hydrogen recombiners and/or vent and purge systems required by 10CFR50.44(b)(3) was intended to address the limited quantity and rate of hydrogen generation that was postulated from a design-basis LOCA. The NRC found that this hydrogen release is not risk-significant because the design-basis LOCA hydrogen release does not contribute to the conditional probability of a large release up to approximately 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after the onset of core damage. In addition, these systems were ineffective at mitigating hydrogen releases from risk-significant beyond design-basis accidents. Therefore, the NRC eliminated the hydrogen release associated with a design-basis LOCA from 10CFR50.44 and the associated requirements that necessitated the need for the hydrogen recombiners and the backup hydrogen vent and purge systems. As a result, the NRC determined that the hydrogen recombiners no longer meet any of the four criteria in 10 CFR 50.36(c)(s)(ii) for retention in Technical Specifications and the existing TS requirements may, therefore, be eliminated for all plants.

Section 2.4 Page 14 Rev. 74 May 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.5 ELECTRICAL POWER SYSTEMS 2.5.1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES OPERATIONAL REQUIREMENTS Primary and backup containment penetration conductor overcurrent protective devices associated with each primary containment electrical penetration circuit shall be OPERABLE. The scope of these protective devices excludes those circuits for which credible fault currents would not exceed the electrical penetrations' design ratings.

APPLICABILITY MODES 1, 2, and 3.

ACTION 3.5.1

a. With one or more of the required containment penetration conductor overcurrent protective devices inoperable, evaluate the affected system or component for operability and enter the appropriate Technical Specification and/or ORM ACTION for the affected system and:

1. For 6.9-kV circuit breakers, remove the 6.9-kV circuit(s) from service by racking out the breaker within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and verify the inoperable breaker(s) to be racked out at least once per 7 days thereafter.

2. For lower voltage circuit breakers (excluding the upper containment polar crane), de-energize the inoperable circuit by tripping and taking appropriate administrative controls for the associated redundant circuit breaker(s) for molded case circuit breakers [or by racking out the associated redundant circuit breaker(s) for unit substation circuit breakers] within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and verify the redundant circuit breaker to be tripped at least once per 7 days thereafter.

3. For the upper containment polar crane containment penetration conductor overcurrent protective devices (cubicle 7B C08 relays and trip circuit of breaker 3B of panel 1AP11E) or circuit breaker 7B of panel 1AP11E inoperable, declare the polar crane inoperable and de-energize the inoperable circuit by racking out circuit breaker 7B of panel 1AP11E within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and verify circuit breaker 7B of panel 1AP11E to be racked out at least once per 7 days thereafter.

Section 2.5 Page 1 Rev. 70 July 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.5.1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES (continued)

ACTION (continued)

b. The provisions of Operational Requirement 1.2.4 are not applicable to overcurrent devices in 6.9-kV circuits which have their inoperable circuit breakers racked out or to lower voltage circuits which have the redundant circuit breaker tripped.

TESTING REQUIREMENTS 4.5.1 Each of the required containment penetration conductor overcurrent protective devices shall be demonstrated OPERABLE:

a. At least once per 72 months:

1. By verifying that all medium voltage 6.9-kV and polar crane circuit breakers are OPERABLE by performing:

a) A CHANNEL CALIBRATION of the associated protective relays, and b) An integrated system functional test which includes simulated automatic actuation of the system and verifying that each relay and associated circuit breakers and overcurrent control circuits function as designed.

2. By subjecting each 6.9-kV and polar crane circuit breaker to an inspection and preventive maintenance in accordance with procedures prepared in conjunction with its manufacturer's recommendations.

b. At least once per 96 months:

1. By selecting and functionally testing all low voltage molded case circuit breakers. Testing of these circuit breakers shall consist of injecting currents in excess of the breaker's nominal setpoint and measuring the response time of the long time delay and short time delay trip elements and setpoint of the instantaneous element where applicable. The measured response time shall be compared to the manufacturer's data to ensure that it is less than or equal to a value specified by the manufacturer.

2. By subjecting each low voltage molded case circuit breaker to an inspection and preventive maintenance in accordance with procedures prepared in conjunction with its manufacturer's recommendations.

Section 2.5 Page 2 Rev. 70 July 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.5.1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES (continued)

BASES 5.5.1 Containment electrical penetrations and penetration conductors are protected by demonstrating the OPERABILITY of primary and backup overcurrent protection circuit breakers by periodic surveillance. The low-frequency motor generator set electrical power supply to the reactor recirculation pumps is provided with one overcurrent protection circuit breaker since the generator's maximum output under fault conditions is less than the penetration's design rating. The surveillance requirements applicable to lower voltage circuit breakers provides assurance of breaker reliability by testing all circuits breakers within the specified period.

Section 2.5 Page 3 Rev. 70 July 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.5.2 MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION OPERATIONAL REQUIREMENTS The thermal overload protection of each valve in safety systems with a bypass device(s) integral with the motor starter shall be bypassed continuously for those directions for which the valve performs an active safety function.

APPLICABILITY Whenever the motor operated valve is required to be OPERABLE.

ACTION 3.5.2 With the thermal overload protection for one or more of the above required valves not bypassed continuously in the valves safety direction(s), continuously bypass the affected thermal overload within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or declare the affected valve(s) inoperable and apply the appropriate Technical Specification and/or ORM ACTION statement(s) for the affected system(s). When thermal overload protection is provided during maintenance, testing, or valve repositioning during normal operation, the time should be minimized and the bypass returned to service as soon as practicable. The 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months limitation applies under these conditions. If an emergency condition occurs demanding valve repositioning, return the thermal overload bypass circuitry to service.

TESTING REQUIREMENTS 4.5.2.1 The thermal overload protection for the above required valves shall be verified to be bypassed continuously in the valves' safety direction(s):

a. At least once per 6 years, and

b. Following maintenance on the motor starter.

4.5.2.2 The thermal overload protection for the above required valves shall be verified to be bypassed in the valves' safety direction(s) following maintenance, testing, or valve repositioning during normal operations during which the thermal overload protection was temporarily placed in force.

BASES 5.5.2 The bypassing of the motor-operated valves thermal overload protection continuously ensures that the thermal overload protection will not prevent safety-related valves from performing their function. The Surveillance Requirements for demonstrating the bypassing of the thermal overload protection continuously are in accordance with Regulatory Guide 1.106 "Thermal Overload Protection for Electric Motors on Motor-Operated Valves," Revision 1, March 1977.

Section 2.5 Page 4 Rev. 70 July 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.5.3 ELECTRICAL POWER SYSTEMS OPERATIONAL REQUIREMENTS Battery cell parameters for the Division 1, 2, 3, and 4 batteries shall be within the limits of Table 2.5.3-1.

APPLICABILITY When the associated battery is required to be OPERABLE.

ACTIONS (NOTE: Separate condition entry is allowed for each battery.)

3.5.3.1 With one or more batteries with one or more battery cell parameters not within Table 2.5.3-1 Category A or B limits,

a. Verify pilot cell's electrolyte level and float voltage meet Table 2.5.3-1 Category C limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and

b. Verify battery cell parameters meet Table 2.5.3-1 Category C limits within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and once per 7 days thereafter, and

c. Restore battery cell parameters to Category A and B limits of Table 2.5.3-1 within 31 days.

3.5.3.2 With required actions associated with 3.5.3.1 not met, or with one or more batteries with average electrolyte temperature of the representative cells <65 F, or with one or more batteries with one or more battery cell parameters not within Category C limits, immediately declare the associated battery inoperable.

TESTING REQUIREMENTS 4.5.3.1 Verify battery cell parameters meet Table 2.5.3-1 Category A limits at least once per 7 days.

4.5.3.2 Verify battery cell parameters meet Table 2.5.3-1 Category B limits at least once per 92 days and once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after a battery overcharge of > 150V.

4.5.3.3 Verify average electrolyte temperature of representative cells is > 65 F at least once per 92 days.

Section 2.5 Page 5 Rev. 70 July 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.5.3 ELECTRICAL POWER SYSTEMS (continued)

TABLE 2.5.3-1 BATTERY CELL PARAMETER REQUIREMENTS CATEGORY A:

CATEGORY B: CATEGORY C:

LIMITS FOR EACH PARAMETER LIMITS FOR EACH LIMITS FOR EACH DESIGNATED PILOT CONNECTED CELL CONNECTED CELL CELL Electrolyte > Minimum level > Minimum level Above top of plates, Level indication mark, and < indication mark, and < and not overflowing 1/4 inch above 1/4 inch above maximum maximum level level indication mark (a) indication mark (a)

Float Voltage > 2.13V > 2.13V > 2.10V Specific > 1.195 > 1.190 Not more than 0.020 Gravity (b) (c) below average of all AND connected cells Average of all connected AND cells > 1.200 Average of all connected cells > 1.190 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during equalizing charges provided it is not overflowing.

(b) Corrected for electrolyte temperature and level. However, level correction is not required when battery charging is < 2 amps when on float charge.

(c) A battery charging current of < 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

Section 2.5 Page 6 Rev. 70 July 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6 REFUELING OPERATIONS 2.6.1 DECAY TIME -- REFUELING OPERATIONS OPERATIONAL REQUIREMENTS The reactor shall be subcritical for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

APPLICABILITY MODE 5, during movement of irradiated fuel in the reactor pressure vessel.

ACTION 3.6.1 With the reactor subcritical for less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , suspend all operations involving movement of irradiated fuel in the reactor pressure vessel.

TESTING REQUIREMENTS 4.6.1 The reactor shall be determined to have been subcritical for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verification of the date and time of subcriticality prior to movement of irradiated fuel in the reactor pressure vessel.

BASES 5.6.1 The minimum requirement for reactor subcriticality prior to fuel movement ensures that sufficient time has elapsed to allow the radioactive decay of the short lived fission products. This decay time is consistent with the assumptions used in the safety analyses.

Section 2.6 Page 1 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.2 COMMUNICATIONS - REFUELING OPERATIONS OPERATIONAL REQUIREMENTS Direct communication shall be maintained between the control room and refueling platform personnel.

APPLICABILITY MODE 5, during CORE ALTERATIONS*.

Except movement of control rods with their normal drive system.

ACTION 3.6.2 When direct communication between the control room and refueling platform personnel cannot be maintained, immediately suspend CORE ALTERATIONS.

TESTING REQUIREMENTS 4.6.2 Direct communication between the control room and refueling platform personnel shall be demonstrated at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months during CORE ALTERATIONS*.

Except movement of control rods with their normal drive system.

BASES 5.6.2 The requirement for communications capability ensures that refueling platform personnel can be promptly informed of significant changes in the facility status or core reactivity condition during movement of fuel within the reactor pressure vessel.

Section 2.6 Page 2 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.3 REFUELING PLATFORM -- REFUELING OPERATIONS OPERATIONAL REQUIREMENTS The refueling platform shall be OPERABLE and used for handling fuel assemblies or control rods, either:

a) within the reactor pressure vessel, or b) during operations associated with the Inclined Fuel Transfer System (IFTS).

APPLICABILITY During handling of fuel assemblies or control rods, either:

a) within the reactor pressure vessel, or b) during operations associated with the IFTS.

ACTION 3.6.3 With the requirements for refueling platform OPERABILITY not satisfied, suspend use of any inoperable refueling platform equipment from operations involving the handling of control rods and fuel assemblies within the reactor pressure vessel, or the IFTS, after placing the load in a safe condition.

TESTING REQUIREMENTS 4.6.3 Each refueling platform crane or hoist used for handling of control rods or fuel assemblies within the reactor pressure vessel, or the IFTS, shall be demonstrated OPERABLE within 7 days prior to the start of such operations with that crane or hoist by:

a. Demonstrating operation of the overload cutoff on the main hoist when the load exceeds 1600 +/- 50 pounds.

b. Demonstrating operation of the overload cutoff on the frame mounted, 500 lb, and monorail hoists when the load exceeds 500 +/- 50 pounds.

c. Demonstrating operation of the uptravel interlock to maintain the top of the active fuel or control rods to > 8 feet 6 inches below the water level.

d. Deleted.

e. Demonstrating operation of the slack cable cutoff on the main hoist when the load is less than 50 +/- 10 pounds.

Section 2.6 Page 3 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.3 REFUELING PLATFORM - REFUELING OPERATIONS (continued)

f. Demonstrating operation of the loaded interlock on the main hoist when the load exceeds 700 +/- 50 pounds.

g. Demonstrating operation of the main hoist raise power cutoff when the refueling platform area radiation monitor dose rate exceeds 50 mR/hr.

h. Demonstrating operation of the redundant loaded interlock (rod block) on the main hoist when the load exceeds 700 +/- 50 pounds.

BASES 5.6.3 The OPERABILITY requirements ensure that the appropriate fuel handling equipment will be used for handling control rods and fuel assemblies during operations associated with the IFTS and within the reactor pressure vessel, that each crane and hoist has sufficient load capacity for handling fuel assemblies and/or control rods, and that the core internals and pressure vessel are protected from excessive lifting force in the event they are inadvertently engaged during lifting operations.

Section 2.6 Page 4 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.4 Deleted Section 2.6 Page 5 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.5 CRANE TRAVEL - SPENT FUEL STORAGE POOL, CASK STORAGE POOL, UPPER CONTAINMENT FUEL POOL, AND NEW FUEL STORAGE VAULT -

REFUELING OPERATIONS OPERATIONAL REQUIREMENTS Loads in excess of 1000 pounds shall be prohibited from travel over fuel assemblies in the spent fuel storage racks in the spent fuel storage and cask storage pools, upper containment fuel pool racks or new fuel storage vault racks.

APPLICABILITY With fuel assemblies in the spent fuel storage pool racks in the spent fuel storage and cask storage pools, upper containment fuel pool racks, or the new fuel storage vault racks.

ACTION 3.6.5 With the requirements of the above Operational Requirement not satisfied, place the crane load in a safe condition. The provisions of Operational Requirement 1.2.3 are not applicable.

TESTING REQUIREMENTS 4.6.5.1 Crane physical stops which prevent fuel building overhead crane travel with loads in excess of 1000 pounds over fuel assemblies in the spent fuel storage pool racks shall be demonstrated OPERABLE (except as allowed per License Amendment 170 as described in ORM Bases 5.6.5):

a. Within 7 days prior to handling loads with the fuel building overhead crane, and

b. At least once per 7 days while handling loads with the fuel building overhead crane.

4.6.5.2 Loads other than fuel assemblies or control rods shall be verified to weigh less than or equal to 1000 pounds before travel over fuel assemblies in the upper containment fuel storage pool or the new fuel storage vault racks.

BASES 5.6.5 The restriction on movement of loads in excess of the nominal weight of a fuel assembly over other fuel assemblies in the pools ensures that in the event this load is dropped 1) the activity release will be limited to that contained in a single fuel assembly, and 2) any possible distortion of fuel in the storage racks will not result in a critical array. This assumption is consistent with the activity release assumed in the safety analyses. The fuel building overhead crane physical stops preclude travel of the fuel building overhead crane over the fuel building spent fuel storage pool racks. The stops also ensure that handling of heavy loads is within the guidelines of NUREG-0612 which precludes dropping a heavy load onto safety-related equipment. Although weighing more than 1000 pounds itself, the fuel building overhead crane main hoist load block need not be considered a load provided no loads are being handled by the fuel building overhead crane and the main hoist load block is secured in accordance with plant rigging procedures for single failure proof rigging. This will ensure that Section 2.6 Page 6 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.5 CRANE TRAVEL - SPENT FUEL STORAGE POOL, CASK STORAGE POOL, UPPER CONTAINMENT FUEL POOL, AND NEW FUEL STORAGE VAULT -

REFUELING OPERATIONS (continued) movement of the load block is in accordance with NUREG- 0612. With these controls in force, the crane physical stops may be removed and the secured load block allowed to travel over the fuel building spent fuel storage pool. The physical stops do not prevent the crane from traveling over the cask storage pool.

License Amendment 170 was approved for the Clinton Power Station Onsite Spent Fuel Storage Expansion project. Consistent with the license amendment request and the NRCs Safety Evaluation, Amendment 170 allows the Fuel Building Crane (1HC07G) to be used as an alternate crane if the temporary crane is inoperable. This allows 1HC07G functional access over the spent fuel pool (SFP) for this project. This permits the crane physical stops to be removed without securing the main hoist load block for the duration of the Spent Fuel Pool Expansion project.

Barriers will be established in procedures to ensure the safe load path is used and that no heavy loads travel over fuel, as follows:

1. Whenever the Fuel Building Crane is operated past (east of) the bridge travel limit switch setpoint, a dedicated spotter in direct communication with the crane operator will be assigned to ensure that loads in excess of 1000 pounds are prohibited from traveling over fuel assemblies.

2. Whenever the Fuel Building Crane physical stops do not restrict crane travel over the SFP, either:

a. A crane operator is stationed in the area to prevent unauthorized activities until physical travel stops are repositioned, or,

b. An equipment status tag is hung on the crane disconnect to alert the crane operator that the crane travel stops have been moved and will not restrict crane travel over the SFP.

Section 2.6 Page 7 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.6 INCLINED FUEL TRANSFER SYSTEM - REFUELING OPERATIONS OPERATIONAL REQUIREMENTS The following conditions shall be met for the inclined fuel transfer system (IFTS):

1. Transferring non-irradiated components:

a. At least one IFTS carriage position indicator shall be OPERABLE at each carriage position;

b. At least one liquid level sensor shall be OPERABLE;

c. The blocking valve located in the fuel building IFTS hydraulic power unit shall be OPERABLE.

2. In addition to Operational Requirements l.a, l.b, and l.c above, when transferring irradiated components:

a. The access doors (including removable shields) of all rooms through which the transfer system penetrates shall be closed and locked;

b. All access doors (including removable shields) interlocks shall be OPERABLE;

c. Any keylock switch that provides IFTS access control-transfer system lockout shall be OPERABLE.

APPLICABILITY During IFTS operation.

ACTION 3.6.6 With the requirements of the above Operational Requirement not satisfied, suspend IFTS operation with the IFTS at either terminal point. The provisions of Operational Requirement 1.2.3 are not applicable.

TESTING REQUIREMENTS 4.6.6.1 Verify prior to use and once per 30 days during operation of the IFTS:

a. At least one IFTS carriage position indicator is OPERABLE at each carriage position,

b. At least one liquid level indicator is OPERABLE, and

c. The blocking valve in the Fuel Building IFTS hydraulic power unit is OPERABLE.

Section 2.6 Page 8 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.6 INCLINED FUEL TRANSFER SYSTEM - REFUELING OPERATIONS (continued) 4.6.6.2 Verify the following within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to transfer of irradiated components with the IFTS:

a. No personnel are in areas immediately adjacent to the IFTS, and

b. All access doors (including removable shields) to rooms through which the IFTS penetrates are closed and locked.

4.6.6.3 Verify prior to use and once per 30 days during transfer of irradiated components with the IFTS:

a. All access door (including removable shields) interlocks are OPERABLE, and

b. The keylock switches which provide IFTS access or control-transfer system lockout are OPERABLE.

BASES 5.6.6 The purpose of the inclined fuel transfer system specification is to control personnel access to those potentially high radiation areas immediately adjacent to the system and to assure safe operation of the system.

Section 2.6 Page 9 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 2.6.7 MODE SWITCH POSITION OPERATIONAL REQUIREMENTS The reactor mode switch shall be locked in the Shutdown or Refuel position*.

Except as provided in Technical Specification Special Operations LCO 3.10.2 and 3.10.8.

APPLICABILITY MODE 4**, 5 ACTION 3.6.7 With the reactor mode switch not locked in the Shutdown or Refuel position as specified, suspend CORE ALTERATIONS and lock the reactor mode switch in the Shutdown or Refuel position.

TESTING REQUIREMENTS 4.6.7 The reactor mode switch shall be verified to be locked in the Shutdown or Refuel Position at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

- When the contained water volume of the suppression pool is less than 98,700 ft3, which is equivalent to a suppression pool level of 12' 8", or Technical Specification 3.10.4 is being utilized.

Section 2.6 Page 10 Rev. 71 November 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.0 ADMINISTRATIVE REQUIREMENTS 6.1 Administrative Requirements are contained in Section 13.1.2.3 of the USAR for operating shift crews (USAR Change Package 8-215).

6.2 Not Used 6.3 Not Used 6.4 TRAINING 6.4.1 A retraining and replacement training program for the unit staff shall be maintained under the direction of the Director-Operations Training and shall meet or exceed the requirements of 10 CFR Part 55.

Section 6 Page 1 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.5 REVIEW AND AUDIT 6.5.1 PLANT OPERATIONS REVIEW COMMITTEE (PORC)

Refer to USAR Section 13.4.1, "Plant Operations Review Committee."

6.5.2 NUCLEAR SAFETY REVIEW BOARD (NSRB)

Refer to Updated Safety Analysis Report section 13.4.2, Nuclear Safety Review Board.

6.5.3 TECHNICAL REVIEW AND CONTROL ACTIVITIES Procedures required by Technical Specification 5.4.1 and ORM 6.8 and other procedures which affect plant nuclear safety as determined by the Manager-Clinton Power Station or the responsible manager* and changes thereto, other than editorial or typographical changes, shall be reviewed as follows:

6.5.3.1 TECHNICAL REVIEW

a. Each such procedure or procedure change shall be independently reviewed by an individual knowledgeable in the area affected other than the individual who prepared the procedure, or procedure change. The applicable Department Head/Designee shall approve all plant procedures and changes thereto, prior to implementation.

b. Individuals responsible for reviews performed in accordance with Item 6.5.3.1.a above shall be designated by the Manager-Clinton Power Station or the responsible manager*. Each such review shall include a determination of whether or not additional, cross-disciplinary, review is necessary. If deemed necessary, such review shall be performed by the review personnel of the appropriate discipline.

Individuals performing these reviews shall meet or exceed the qualifications stated in ANSI/ANS 3.1-1978 for the appropriate discipline.

c. When a review pursuant to 10 CFR 50.59 is required, it shall be included in the procedure or the procedure change review. Pursuant to 10 CFR 50.59, NRC approval of items requiring NRC review shall be obtained prior to the Manager-Clinton Power Station approval for implementation.

d. Written records of reviews performed in accordance with Item 6.5.3.1.a above, including recommendations for approval or disapproval, shall be prepared and maintained.

[*The responsible manager must be the equivalent of the Manager - Clinton Power Station with respect to his/her level of responsibility within corporate structure.]

Section 6 Page 2 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.6 REPORTABLE EVENT ACTION 6.6.1 The following actions shall be taken for any of those conditions identified in 10CFR50.73:

a. The Commission shall be notified and a report submitted pursuant to the requirements of 10CFR50.73, and

b. The reportable event shall be reviewed by the PORC.

c. The report shall be submitted to the NSRB and the CPS Site Vice President.

Section 6 Page 3 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.7 SAFETY LIMIT VIOLATION 6.7.1 The following actions shall be taken in the event a Safety Limit is violated:

a. The CPS Site Vice President, Manager-Clinton Power Station, and the NSRB shall be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. The Safety Limit Violation Report shall be reviewed by the PORC. This report shall describe: (1) applicable circumstances preceding the violation, (2) effects of the violation upon unit components, systems, or structures, and (3) corrective action taken to prevent recurrence.

c. The Safety Limit Violation Report shall be submitted to the CPS Site Vice President, Manager-Clinton Power Station, and the NSRB within 30 days of the violation.

Section 6 Page 4 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.8 PROCEDURES AND PROGRAMS PROCEDURES 6.8.1 Written procedures shall be established, implemented, and maintained covering the activities referenced below:

a. Refueling operations;

b. Surveillance and test activities of safety-related equipment;

c. Security Plan implementation;

d. Emergency Plan implementation;

e. Fire Protection Program implementation;

f. Process Control Program implementation; and

g. Offsite Dose Calculation Manual implementation.

REVIEW AND APPROVAL 6.8.2 Each procedure of Technical Specification 5.4.1 and Operational Requirement 6.8.1 and changes thereto, shall be reviewed in accordance with Updated Safety Analysis Report section 13.4.1 and Operational Requirement 6.5.3 as applicable and shall be approved by the applicable Department Head/Designee prior to implementation and reviewed periodically as set forth in administrative procedures.

TEMPORARY CHANGES 6.8.3 Temporary changes to procedures of Technical Specification 5.4.1 and Operational Requirement 6.8.1 may be made provided:

a. The intent of the original procedure is not altered;

b. The change is approved by two members of the unit management staff, at least one of whom holds a Senior Operator license on the unit affected; and

c. The change is documented, reviewed in accordance with Updated Safety Analysis Report section 13.4.1 and Operational Requirement 6.5.3 as appropriate, and approved by the applicable Department Head/Designee within 14 days of implementation.

Section 6 Page 5 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.8 PROCEDURES AND PROGRAMS (continued) 6.8.4 The following programs shall be established, implemented, and maintained:

a. In-Plant Radiation Monitoring A program which will ensure the capability to accurately determine the airborne iodine concentration in vital areas under accident conditions.

This program shall include the following:

1. Training of personnel,

2. Procedures for monitoring, and

3. Provisions for maintenance of sampling and analysis equipment.

b. Fire Protection Program A program to implement and maintain in effect all provisions of the approved fire protection program as described in the Updated Safety Analysis Report as amended, and as approved in the Safety Evaluation Report (NUREG-0853) dated February 1982 as supplemented. Noncompliance with the above Fire Protection Systems described in plant procedure CC-AA-211 shall be reported in accordance with Operational Requirement 6.6.1.

c. Radiological Environmental Monitoring Program A program shall be provided to monitor the radiation and radionuclides in the environs of the plant. The program shall provide (1) representative measurements of radioactivity in the highest potential exposure pathways, and (2) verification of the accuracy of the effluent monitoring program and modeling of environmental exposure pathways. The program shall (1) be contained in the ODCM, (2) conform to the guidance of Appendix I to 10 CFR Part 50, and (3) include the following:

1. Monitoring, sampling, analysis, and reporting of radiation and radionuclides in the environment in accordance with the methodology and parameters in the ODCM;

2. A Land Use Census to ensure that changes in the use of areas at and beyond the SITE BOUNDARY are identified and that modifications to the monitoring program are made if required by the results of this census; and

3. Participation in an Interlaboratory Comparison Program to ensure that independent checks on the precision and accuracy of the measurements of radioactive materials in environmental sample matrices are performed as part of the quality assurance program for environmental monitoring.

Section 6 Page 6 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.9 REPORTING REQUIREMENTS STARTUP REPORT 6.9.1.1 Summary report of plant startup and power escalation testing shall be submitted following (1) receipt of an Operating License, (2) amendment to the license involving a planned increase in power level, (3) installation of fuel that has a different design or has been manufactured by a different fuel supplier, and (4) modifications that may have significantly altered the nuclear, thermal, or hydraulic performance of the unit.

6.9.1.2 The startup report shall address each of the tests identified in the Updated Safety Analysis Report and shall include a description of the measured values of the operating conditions or characteristics obtained during the test program and a comparison of these values with design predictions and specifications. Any corrective actions that were required to obtain satisfactory operation shall also be described. Any additional specific details required in license conditions based on other commitments shall be included in this report.

6.9.1.3 Startup reports shall be submitted within (1) 90 days following completion of the startup test program, (2) 90 days following resumption or commencement of commercial power operation, or (3) 9 months following initial criticality, whichever is earliest. If the startup report does not cover all three events (i.e., initial criticality, completion of startup test program, and resumption or commencement of commercial operation) supplementary reports shall be submitted at least every 3 months until all three events have been completed.

OTHER REPORTS 6.9.2 If an individual emergency diesel generator (EDG) experiences four or more valid failures in the last 25 demands, these failures and any non-valid failures experienced by that EDG in that time period shall be reported to the Commission within 30 days.

Reports of diesel generator failures shall include the information recommended in Regulatory Position C.3.b of Regulatory Guide 1.108, Revision 1, August 1977.

Section 6 Page 7 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM) 6.10 RECORD RETENTION Record retention requirements are contained in the Exelon Standard Records Retention Schedule (SRRS).

6.11 RADIATION PROTECTION PROGRAM 6.11.1 Procedures for personnel radiation protection shall be prepared consistent with the requirements of 10 CFR Part 20 and shall be approved, maintained, and adhered to for all operations involving personnel radiation exposure.

6.12 Not Used 6.13 PROCESS CONTROL PROGRAM (PCP)

The Process Control Program shall contain the current formula, sampling, analyses, tests, and determinations to be made to ensure that the processing and packaging of solid radioactive wastes based on demonstrated processing of actual or simulated wet solid wastes will be accomplished in such a way as to assure compliance with 10 CFR Part 20, 10 CFR Part 61, 10 CFR Part 71 and Federal and State regulations, burial ground requirements and other requirements governing the disposal of the radioactive waste.

Changes to the PCP:

a. Shall be documented and records of reviews performed shall be retained as required by the Exelon Standard Record Retention Schedule.

This documentation shall contain:

1. Sufficient information to support the change together with the appropriate analyses or evaluations justifying the change(s), and

2. A determination that the change will maintain the overall conformance of the solidified waste product to existing requirements of Federal, State, or other applicable regulations.

b. Shall become effective after review and acceptance by the PORC and the approval of the Manager - Clinton Power Station.

Section 6 Page 8 Rev. 42 September 2004

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

REMOTE SHUTDOWN INSTRUMENTS AND CONTROLS This attachment contains the list of instrumentation required by Technical Specification LCO 3.3.3.2.

REMOTE SHUTDOWN MONITORING INSTRUMENTATION DIVISION I DIVISION II MINIMUM MINIMUM EQUIPMENT EQUIPMENT CHANNELS CHANNELS INSTRUMENT NUMBER NUMBER OPERABLE OPERABLE

1. SRV 51D Temp. Supp. 1C61-R506 1 1C61-R513 1 Pool Temp.

2. SRV 51C Temp. Supp. 1C61-R507 1 1C61-R514 1 Pool Temp

3. SRV 51G Temp. Supp. 1C61-R508 1 1C61-R512 1 Pool Temp

4. Supp. Pool Level 1C61-R504 1 1C61-R511 1

5. RPV Level 1C61-R010 1 1C61-R509 1

6. RPV Pressure 1C61-R011 1 1C61-R510 1

7. Upper DW Temp. 1C61-R501 1 N/A N/A

8. Lower DW Temp. 1C61-R502 1 N/A N/A

9. SX Strainer. Dsch. Outlet 1C61-R503 1 1PI-SX024B 1 Press.

10. RCIC Cond. Storage 1C61-R505 1 N/A N/A Tank Level

11. RHR Loop Flow 1C61-R005 1 1E12-R008B* 1

12. RCIC Turb. Speed 1C61-R003 1 N/A N/A

13. RCIC Pump Flow 1C61-R001 1 N/A N/A

14. RCIC Turb. Flow 1C61-R001 1 N/A N/A Control.

Division II RHR pump flow is determined by RHR pump discharge pressure instrumentation at panel 1H22-P021. Page 1 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

REMOTE SHUTDOWN INSTRUMENTS AND CONTROLS REMOTE SHUTDOWN SYSTEM CONTROLS MINIMUM CHANNELS EQUIPMENT OPERABLE CONTROL NUMBER DIVISION 1 DIVISION 2

l. RHR Pump 1E12-C002A/B 1 1

2. RHR Supp. Pool Suction Vlv. 1E12-F004A/B 1 1

3. RHR A Shutdown Cooling Suction Vlv. 1E12-F006A 1 N/A

4. RHR Shutdown Cooling Supply Outbd. 1E12-F008 1 N/A Isol. Vlv.

5. RHR HX Bypass Vlv. 1E12-F048A/B 1 1

6. RHR Test Line Vlv. to Supp. Pool 1E12-F024A/B 1 1

7. RHR HX Dsch. Vlv. 1E12-F003 A/B 1 1

8. Deleted

9. RHR HX Inlet Vlv. 1E12-F047A/B 1 1

10. RHR HX SX Outlet Vlv 1E12-F068A/B 1 1 1 l. RHR Shutdown Cooling Return Vlv. 1E12-F053A/B 1 1

12. RHR RPV Inboard Inject. Vlv 1E12-F042A/B 1 1

13. RHR RPV Outboard Inject. Vlv. 1E12-F027A 1 N/A

14. RHR Cnmt. Spray Vlv. 1E12-F028A 1 N/A

15. Deleted

16. Deleted

17. RHR FP/FC Supply Vlv. Note (a) 1E12-F037A 1 N/A

18. RHR Pump Min. Flow Recirc. Vlv. 1E12-F064A/B 1 1

19. Deleted

20. RHR B Shutdown Cooling Suction Vlv 1E12-F006B N/A 1

21. Shutdown Cooling Inboard. Isol. Vlv. 1E12-F009 N/A 1

22. RPV Head Spray Vlv. 1E12-F023 N/A 1

23. Deleted

24. RCIC Pump Cond. Stg. Tnk. Suction Vlv 1E51-F010 1 N/A

25. RCIC Supp. Pool Suction Vlv. 1E51-F031 1 N/A

26. RCIC First Test Line Isol. Vlv. To RCIC 1E51-F022 1 N/A Storage Tank

27. RCIC Inject. Vlv 1E51-F013 1 N/A

28. RCIC Min. Flow Recirc. Vlv. 1E51-F019 1 N/A

29. RCIC Second Test Line Isol. Vlv. To 1E51-F059 1 N/A RCIC Stg. Tnk.

30. RCIC Turbine L.O. Cooling Water Supply 1E51-F046 1 N/A Valve

31. RCIC Gland Seal Air Cmpsr. 1E51-C002F 1 N/A Page 2 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

REMOTE SHUTDOWN INSTRUMENTS AND CONTROLS REMOTE SHUTDOWN SYSTEM CONTROLS MINIMUM CHANNELS EQUIPMENT OPERABLE CONTROL NUMBER DIVISION 1 DIVISION 2

32. RCIC Outbd. Vac. Bkr. Vlv. 1E51-F077 1 N/A

33. RHR/RCIC Stm. Sply. Otbd. Isol. Vlv. 1E51-F064 1 N/A

34. RCIC Turb. Stm. Sply. Vlv. 1E51-F045 1 N/A

35. RCIC Turb. Xhst. Stop Vlv. 1E51-F068 1 N/A

36. RCIC Trip/Throttle Vlv. 1E51-C002E 1 N/A

37. RCIC Turb. Stm. Supply Warm-up Vlv. 1E51-F076 N/A 1

38. SRV 51C 1B21-F051C 1 1

39. SRV 51D 1B21-F051D 1 1

40. SRV 51G 1B21-F051G 1 1

41. RCIC Stm. Flow Cntrl. N/A 1 N/A

42. RCIC Turb. Trip N/A 1 N/A

43. DG 1A Vent. Fan 1VD01CA 1 N/A

44. DG 1A Oil Rm. A Xhst. Fan 1VD02CA 1 N/A

45. Div. 1 Switchgear Heat Removal Vent. 1VX03CA 1 N/A Fan

46. Battery Rm. 1A1 Xhst. Fan 1VX05CA 1 N/A

47. SX Pump. Rm. Sply. Fan 1VH01CA/B 1 1

48. RHR Pump. Rm. 1A Sply. Fan 1VY02C 1 N/A

49. RHR Ht. Xchg. Rm. A Sply. Fan 1VY03C 1 N/A

50. RCIC Pump. Rm. Sply. Fan 1VY04C 1 N/A

51. DG lA Ckt. Brkr 252-DGKA 1 N/A

52. DG 1A Fuel Oil Transfer Pump 1DO01PA 1 N/A

53. SX Pump 1SX01PA/B 1 1

54. SX/WS Isol. Vlv. 1SX014A/B 1 1

55. DG 1A OutletVlv. 1SX063A 1 N/A

56. SX 1A Strainer Inlet Vlv. Note (a) 1SX003A 1 N/A

57. SX 1A Strainer Outlet Vlv. Note (a) 1SX004A 1 N/A

58. SX 1A Strainer Bypass Vlv. 1SX008A 1 N/A

59. SX Xtie. Vlv. 1SX011A 1 N/A

60. RHR Ht. Xchg. 1A Demin. Water Supply. 1SX082A 1 N/A Vlv.

61. Fuel Pool Ht. Xchg. 1A SX Supply Vlv. 1SX012A 1 N/A

62. Fuel Pool Ht. Xchg. 1A SX Dsch. Vlv. 1SX062A 1 N/A

63. Fuel Pool M/U SX Sply. Vlv. 1SX016A 1 N/A

64. SX-SGTS Charcoal Bed Train A Deluge 1SX073A 1 N/A Vlv.

65. Cntl. Rm. HVAC Recirc. Unit A Deluge 1SX076A 1 N/A Vlv Page 3 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

REMOTE SHUTDOWN INSTRUMENTS AND CONTROLS REMOTE SHUTDOWN SYSTEM CONTROLS MINIMUM CHANNELS EQUIPMENT OPERABLE CONTROL NUMBER DIVISION 1 DIVISION 2

66. Cntl. Rm. HVAC M/U Unit A Deluge Vlv 1SX107A 1 N/A

67. RHR HX. Clg. Wtr. Sply. Vlv 1E12-F014A/B 1 1

68. RCIC Inbd. Vac. Bkr. Vlv 1E51-F078 N/A 1

69. RCIC Stm. Sply. Inbd. Isol. Vlv 1E51-F063 N/A 1

70. Remote Transfer Switch 1C61-HS501 N/A N/A

71. Remote Transfer Switch 1C61-HS502 N/A N/A

72. Remote Transfer Switch 1C61-HS508 N/A N/A

73. Remote Transfer Switch 1C61-HS509 N/A N/A

74. Remote Transfer Switch 1C61-HS510 N/A N/A

75. Remote Transfer Switch 1C61-HS511 N/A N/A

76. Remote Transfer Switch 1C61-HS527 N/A N/A

77. Remote Transfer Switch 1C61-HS001 N/A N/A

78. Remote Transfer Switch 1C61-HS002 N/A N/A

79. Remote Transfer Switch 1C61-HS003 N/A N/A

80. Remote Transfer Switch 1C61-HS004 N/A N/A

81. Remote Transfer Switch 1C61-HS005 N/A N/A

82. Remote Transfer Switch 1C61-HS006 N/A N/A

83. Remote Transfer Switch 1C61-HS007 N/A N/A

84. Remote Transfer Switch 1C61-HS008 N/A N/A

85. Remote Transfer Switch 1C61-HS009 N/A N/A

86. Remote Transfer Switch 1C61-HS010 N/A N/A

87. Remote Transfer Switch 1C61-HS011 N/A N/A

88. Remote Transfer Switch 1C61-HS012 N/A N/A

89. Circuit Breaker 252-AT1AA1 1C61-HS565 1 N/A

90. RWCU Pump Suct. Outboard. Isol. Vlv. 1G33-F004 1 N/A

91. Remote Transfer Switch at MCC 1A3 1C61-HS567 N/A N/A

92. MS Line Outboard. Drain Isolation Vlv. 1B21-F019 1 N/A

93. Remote Transfer Switch at MCC 1A3 1C61-HS571 N/A N/A

94. Compress.Gas Hdr. Outboard. Isol. Vlv. 1IA012A 1 N/A

95. Remote Transfer Switch at MCC 1A3 1C61-HS569 N/A N/A

96. Feedwater Shutoff Valve 1B21-F065A 1 N/A

97. Feedwater Shutoff Valve 1B21-F065B 1 N/A

98. Remote Transfer Switch at MCC 1A2 1C61-HS573A N/A N/A

99. Remote Transfer Switch at MCC 1A2 1C61-HS573B N/A N/A Table Notations:

(a) Valve is de-energized with its breaker in the off position. Page 4 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE OF CONTENTS NOTE: This Attachment contains the trip setpoints and response time limits for the instruments that are contained in the Technical Specifications.

Table 1 Reactor Protection System (RPS) Instrumentation Setpoints Table 2 Control Rod Block Instrumentation Trip Setpoints Table 3 End of Cycle Recirculation Pump Trip (EOC-RPT) System Instrumentation Trip Setpoints Table 4 ATWS Recirculation Pump Trip (ATWS-RPT) System Instrumentation Trip Setpoints Table 5 Emergency Core Cooling System (ECCS) Instrumentation Trip Setpoints Table 6 Reactor Core Isolation Cooling (RCIC) System Instrumentation Trip Setpoints Table 7 Primary Containment and Drywell Isolation Instrumentation Trip Setpoints Table 8 Secondary Containment Isolation Instrumentation Trip Setpoints Table 9 Residual Heat Removal (RHR) Containment Spray System Instrumentation Trip Setpoints Table 10 Suppression Pool Makeup (SPMU) System Instrumentation Trip Setpoints Table 11 Loss of Power (LOP) Instrumentation Trip Setpoints Table 12 Reactor Protection System (RPS) Electric Power Monitoring Trip Setpoints Table 13 Reactor Protection System (RPS) Instrumentation Response Time Limits Table 14 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation Response Time Limits Table 15 Main Steam Line Isolation Instrumentation Response Time Limits Table 16 Setpoint for the Control Room Ventilation Radiation Monitor Channels Table 17 Nominal Trip Setpoint Table Page 1 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 1 REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Intermediate Range Monitors

a. Neutron Flux-High 120/125 divisions of full scale

b. Inop N/A

2. Average Power Range Monitors

a. Neutron Flux-High, Setdown < 15 % RTP

b. Flow Biased Simulated Thermal Power- 0.58 (W) + 56% (a)

High and < 111.0% RTP, (b)

c. Neutron Flux-High 118% RTP

d. Inop N/A

3. Reactor Vessel Steam Dome 1065 psig Pressure - High

4. Reactor Vessel Water 8.9 inches above Level - Low, Level 3 instrument zero*

5. Reactor Vessel Water 52.0 inches above Level - High, Level 8 instrument zero* Page 2 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 1 (Continued)

TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

6. Main Steam Line Isolation Valve - Closure 8% closed (c)

7. Dry well Pressure - High 1.68 psig

8. Scram Discharge Volume Water Level - High

a. Transmitter 1C11-N601A 29.85 inches 1C11-N601B 29.85 inches 1C11-N601C 29.85 inches 1C11-N601D 29.85 inches

b. Float Switch 1C11-N013A < 762 ft. 1.375 inches msl 1C11-N013B < 762 ft. 1.125 inches msl 1C11-N013C < 762 ft. 0.75 inches msl 1C11-N013D < 762 ft. 1.125 inches msl

9. Turbine Stop Valve Closure 5% closed

10. Turbine Control Valve Fast Closure, 590 psig Trip Oil Pressure - Low

11. Reactor Mode Switch - Shutdown Position N/A

12. Manual Scram N/A TABLE 1 NOTES (a) The Average Power Range Monitor Scram Function varies as a function of recirculation loop drive flow (W). W is the difference in indicated drive flow (in percent of drive flow which produces the same core flow) between two loop and single loop operation at the same core flow. W = 0 for two loop operation.

W = 8% for single loop operation.

(b) Trip Setpoint is 0.58 (W- W) + 37%(a) when reset for single recirculation loop operation per Technical Specification LCO 3.4.1, "Recirculation Loops Operating."

(c) For the Nominal Trip Setpoint associated with this Function, refer to Table 17 Instrument zero is 759 ft. 11 inches msl.

Instrument zero is 759 ft. 10.5 inches msl.

Instrument zero is 520.62 inches above Reactor Vessel zero. Page 3 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 2 CONTROL ROD BLOCK INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Rod Pattern Control System

a. RWL High Power Setpoint 431 psig*

b. Low Power Setpoint 138.0 +/- 4.8 psig*

2. Reactor Mode Switch-Shutdown Position NA TABLE 2 NOTES

These are turbine first stage pressure values. Page 4 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 3 END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) SYSTEM INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Turbine Stop Valve Closure 5% closed

2. Turbine Control Valve Fast Closure, 590 psig Trip Oil Pressure-Low Page 5 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 4 ATWS RECIRCULATION PUMP TRIP (ATWS-RPT) SYSTEM INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Reactor Vessel Water Level - Low Low, Level 2 -45.5 inches*

2. Reactor Steam Dome Pressure - High 1127 psig TABLE 4 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero. Page 6 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 5 EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. LOW PRESSURE COOLANT INJECTION-A (LPCI)

AND LOW PRESSURE CORE SPRAY (LPCS)

SUBSYSTEMS

a. Reactor Vessel Water Level- -145.5 inches* (a)

Low Low Low, Level 1

b. Drywell Pressure - High 1.68 psig

c. LPCI Pump A Start-Time 5 seconds Delay Logic Card

d. Reactor Vessel Pressure-Low 472 psig (a)

(Injection Permissive)

e. LPCS Pump Discharge Flow - 875 gpm Low (Bypass)

f. LPCI Pump A Discharge 1100 gpm Flow - Low (Bypass)

g. Manual Initiation N/A

2. LPCI B AND C SUBSYSTEMS

a. Reactor Vessel Water Level - -145.5 inches* (a)

Low Low Low, Level 1

b. Drywell Pressure - High 1.68 psig

c. LPCI Pump B Start - Time 5 seconds Delay Logic Card

d. Reactor Vessel Pressure - Low 472 psig (a)

(Injection Permissive)

e. LPCI Pump B and LPCI Pump C 1100 gpm Discharge Flow - Low (Bypass)

f. Manual Initiation N/A Page 7 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 5 (Continued)

EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

3. HIGH PRESSURE CORE SPRAY (HPCS)

SYSTEM

a. Reactor Vessel Water Level - -45.5 inches* (a)

Low Low, Level 2

b. Drywell Pressure - High 1.68 psig

c. Reactor Vessel Water Level - 52.0 inches* (a)

High, Level 8

d. RCIC Storage Tank Level-Low 3.5 inches** (a)

e. Suppression Pool Water 6.5 inches*** (a)

Level - High

f. HPCS Pump Discharge 145 psig Pressure - High (Bypass)

g. HPCS System Flow Rate - 625 gpm Low (Bypass)

h. Manual Initiation N/A

4. AUTOMATIC DEPRESSURIZATION SYSTEM (ADS)

TRIP SYSTEM 1 (LOGIC A AND E)

a. Reactor Vessel Water Level- -145.5 inches* (a)

Low Low Low, Level 1

b. Drywell Pressure - High 1.68 psig

c. ADS Initiation Timer 105 seconds

d. Reactor Vessel Water Level- 8.9 inches*

Low, Level 3 (Confirmatory)

e. LPCS Pump Discharge 145 psig (a)

Pressure - High

f. LPCI Pump A Discharge 125 psig (a)

Pressure - High Page 8 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 5 (Continued)

EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP) 4 AUTOMATIC DEPRESSURIZATION SYSTEM (ADS)

TRIP SYSTEM 1 (LOGIC A AND E) (continued)

g. ADS Drywell Pressure 6.0 minutes Bypass Timer

h. Manual Initiation N/A 5 ADS TRIP SYSTEM 2 (LOGIC B AND F)

a. Reactor Vessel Water -145.5 inches* (a)

Level-Low Low Low, Level 1

b. Drywell Pressure - High 1.68 psig

c. ADS Initiation Timer 105 seconds

d. Reactor Vessel Water 8.9 inches*

Level-Low, Level 3 (Confirmatory)

e. LPCI Pumps B and C 125 psig (a)

Discharge Pressure - High

f. ADS Drywell Pressure 6.0 minutes Bypass Timer

g. Manual Initiation N/A TABLE 5 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero.

- Instrument zero is elevation 739 ft. 10-3/4 inches msl.

- - Instrument zero is elevation 731 ft. 5 inches msl.

(a) For the Nominal Trip Setpoint associated with this Function, refer to Table 17 Page 9 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 6 REACTOR CORE ISOLATION COOLING (RCIC) SYSEM INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

a. Reactor Vessel Water -45.5 inches*

Level - Low Low, Level 2

b. Reactor Vessel Water 52.0 inches*

Level - High, Level 8

c. RCIC Storage Tank Level - Low 3.5 inches**

d. Suppression Pool Water Level - High -8.5 inches***

e. Manual Initiation N/A TABLE 6 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero.

- Instrument zero is 739 ft. 10-3/4 inches msl.

- - Instrument zero is 732 ft. 8 inches msl. Page 10 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 7 PRIMARY CONTAINMENT AND DRYWELL ISOLATION INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. MAIN STEAM LINE ISOLATION

a. Reactor Vessel Water Level - -145.5 inches*

Low Low Low, Level 1

b. Main Steam Line Pressure - Low 849 psig

c. Main Steam Line Flow - High 279 psid

d. Condenser Vacuum - Low 8.5 inches Hg vacuum

e. Main Steam Tunnel 163°F Temperature - High

f. Main Steam Line Turbine Building Temperature - High 1E31 - N559 A, B, C, D (Module 1) < 136.1°F 1E31 - N560 A, B, C, D (Module 2) < 136.1°F 1E31 - N561 A, B, C, D (Module 3) < 136.1°F 1E31 - N562 A, B, C, D (Module 4) < 136.1°F 1E31 - N563 A, B, C, D (Module 5) < 144.1°F

g. Manual Initiation N/A

2. PRIMARY CONTAINMENT AND DRYWELL ISOLATION

a. Reactor Vessel Water Level - -45.5 inches*

Low Low, Level 2

b. Drywell Pressure - High 1.68 psig

c. Reactor Vessel Water Level - Low -45.5 inches*

Low, Level 2 (ECCS Divisions 1 and 2)

d. Drywell Pressure - High 1.68 psig (ECCS Divisions 1 and 2)

e. Reactor Vessel Water Level - Low -45.5 inches*

Low, Level 2 (HPCS NSPS Div. 3 and 4)

f. Drywell Pressure - High 1.68 psig (HPCS NSPS Div. 3 and 4)

g. Containment Building Fuel < 100 mR/hr Transfer Pool Ventilation Plenum Radiation - High Page 11 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 7 PRIMARY CONTAINMENT AND DRYWELL ISOLATION INSTRUMENTATION TRIP SETPOINTS (Continued)

TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

2. PRIMARY CONTAINMENT AND DRYWELL ISOLATION (continued)

h. Containment Building Exhaust < 100 mR/hr Radiation - High

i. Containment Building Continuous < 100 mR/hr Containment Purge (CCP) Exhaust Radiation - High

j. Reactor Vessel Water Level - -145.5 inches*

Low Low Low, Level 1

k. Containment Pressure - High 2.56 psid

l. Manual Initiation N/A

3. REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ISOLATION

a. Auxiliary Building RCIC Steam Line Flow - High 110 inches water

b. RCIC Steam Line Flow - High, Time Delay 8 seconds

c. RCIC Steam Supply Line Pressure - Low 60 psig

d. RCIC Turbine Exhaust 10 psig Diaphragm Pressure - High

e. RCIC Equipment Room Ambient 192°F Temperature - High

f. Main Steam Line Tunnel Ambient 163°F Temperature - High

g. Main Steam Line Tunnel 26 minutes, 48 seconds Temperature Timer

h. Deleted

i. Drywell RCIC Steam Line 179.5 inches water Flow - High

j. Drywell Pressure - High 1.68 psig

k. Manual Initiation N/A Page 12 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 7 PRIMARY CONTAINMENT AND DRYWELL ISOLATION INSTRUMENTATION TRIP SETPOINTS (Continued)

TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

4. REACTOR WATER CLEANUP (RWCU) SYSTEM ISOLATION

a. Differential Flow - High < 59 gpm

b. Differential Flow - Timer 45 seconds

c. RWCU Heat Exchanger Equipment Room 190°F Temperature - High

d. RWCU Pump Rooms Temperature - High < 186.5°F

e. Main Steam Line Tunnel 163°F Ambient Temperature - High

f. Reactor Vessel Water Level - -45.5 inches*

Low Low, Level 2

g. Standby Liquid Control System Initiation N/A

h. Manual Initiation N/A

5. RHR SYSTEM ISOLATION

a. RHR Heat Exchanger Ambient < 144.5°F Temperature - High

b. Reactor Vessel Water Level - 8.9 inches*

Low, Level 3

c. Reactor Vessel Water Level - 8.9 inches*

Low, Level 3

d. Reactor Vessel Water Level - -145.5 inches*

Low Low Low, Level 1

e. Reactor Vessel Pressure - High 104 psig

f. Dry well Pressure - High 1.68 psig

g. Manual Initiation N/A TABLE 7 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero. Page 13 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 8 SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Reactor Vessel Water Level - Low Low, Level 2 -45.5 inches*

2. Drywell Pressure - High 1.68 psig

3. Containment Building Fuel Transfer Pool < 100 mR/hr Ventilation Plenum Exhaust Radiation - High

4. Containment Building Exhaust Radiation - High < 100 mR/hr

5. Containment Building Continuous Containment < 100 mR/hr Purge (CCP) Exhaust Radiation - High

6. Fuel Building Exhaust Radiation - High < 10 mR/hr

7. Manual Initiation N/A TABLE 8 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero. Page 14 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 9 RESIDUAL HEAT REMOVAL (RHR) CONTAINMENT SPRAY SYSTEM INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Drywell Pressure-High 1.68 psig

2. Containment Pressure-High 22.3 psia

3. Reactor Vessel Water Level- -145.5 inches*

Low Low Low, Level 1

4. Timers, System A and System B 610 seconds

5. Timer, System B only 89 seconds

6. Manual Initiation N/A TABLE 9 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero. Page 15 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 10 SUPPRESSION POOL MAKEUP (SPMU) SYSTEM INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT (ATSP)

1. Drywell Pressure-High 1.68 psig

2. Reactor Vessel Water Level- -145.5 inches*

Low Low Low, Level 1

3. Suppression Pool Water 37.6 inches**

Level-Low Low

4. Timer < 25 minutes

5. Manual Initiation N/A TABLE 10 NOTES

Instrument zero is 520.62 inches above Reactor Vessel zero.

- Instrument zero is 727 ft. 0 inches msl. Page 16 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 11 LOSS OF POWER (LOP) INSTRUMENTATION TRIP SETPOINTS TRIP FUNCTION ACTUAL ALLOWABLE VALUE TRIP SETPOINT (ATSP)

1. Division 1 -- 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage#

4.16 kV basis 2870 @

(120-volt basis) (82 volts) (> 67 and < 97 volts)

b. Loss of Voltage - Time Delay # 2.2 seconds @

(inverse relay minimum operating time when offsite voltage is at 0 volts)

c. Degraded Voltage Reset (120-volt basis) (117.52 volts) (> 117.39 and < 117.59 volts)

Phase AB

d. Degraded Voltage Reset (117.66 volts) (> 117.53 and < 117.73 volts)

(120-volt basis)

Phase BC

e. Degraded Voltage Drop-out (120-volt basis) (116.69 volts) (> 115.921 volts)

Phase AB

f. Degraded Voltage Drop-out (116.83 volts) (116.06 volts)

(120-volt basis)

Phase BC

g. Degraded Voltage - Time Delay 15 seconds @

2. Division 2 -- 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage#

4.16 kV basis 2870 @

(120-volt basis) (82 volts) (> 67 and < 97 volts)

b. Loss of Voltage - Time Delay # 2.2 seconds @

(inverse relay minimum operating time when offsite voltage is at 0 volts)

c. Degraded Voltage Reset (120-volt basis) (117.52 volts) (> 117.39 and < 117.58 volts)

Phase AB

d. Degraded Voltage Reset (117.66 volts) (> 117.53 and < 117.73 volts)

(120-volt basis)

Phase BC Page 17 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES

e. Degraded Voltage Drop-out (120-volt basis) (116.69 volts) (> 115.918 volts)

Phase AB

f. Degraded Voltage Drop-out (116.83 volts) (116.06 volts)

(120-volt basis)

Phase BC

g. Degraded Voltage - Time Delay 15 seconds @

3. Division 3 -- 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage#

4.16 kV basis 2520 volts @

(120-volt basis) (72 volts) (> 67 and < 78 volts)

b. Loss of Voltage - Time Delay # 2.5 seconds @

c. Degraded Voltage Reset (120-volt basis) (117.35 volts) (> 117.22 and < 117.42 volts)

Phase AB

d. Degraded Voltage Reset (117.49 volts) (> 117.35 and < 117.55 volts)

(120-volt basis)

Phase BC

e. Degraded Voltage Drop-out (120-volt basis) (116.52 volts)

Phase AB (> 115.753 volts)

f. Degraded Voltage Drop-out (116.66 volts) (> 115.884 volts)

(120-volt basis)

Phase BC

e. Degraded Voltage - Time Delay 15 seconds @

TABLE 11 NOTES

These are inverse time delay voltage relays or instantaneous voltage relays with a time delay. The voltages shown are the pickup voltages of the relay. For the inverse time relays, voltage conditions proportionally below pickup voltage will result in decreased trip times.

@ See Technical Specification Table 3.3.8.1-1.

References:

Calculation 19-AN-19 Amendment 169 to NPF-62 Page 18 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 12 REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TRIP SETPOINTS TRIP FUNCTION ACTUAL TRIP SETPOINT

1. Overvoltage Bus A 125.8 volts Bus B 125.2 volts

2. Undervoltage Bus A 116.5 volts Bus B 116.2 volts

3. Underfrequency Bus A 57.6 Hz Bus B 57.6 Hz Page 19 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 13 REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING RESPONSE TIME LIMITS TRIP FUNCTION RESPONSE TIME (Seconds)

1. Intermediate Range Monitors

a. Neutron Flux - High N/A

b. Inop N/A

2. Average Power Range Monitors*

a. Neutron Flux - High, Setdown N/A

b. Flow Biased Simulated Thermal Power - High < 0.09**

c. Fixed Neutron Flux - High < 0.09

d. Inop N/A

3. Reactor Vessel Steam Dome Pressure - High*** < 0.33

4. Reactor Vessel Water Level - Low, Level 3*** < 1.03

5. Reactor Vessel Water Level - High, Level 8*** < 1.03

6. Main Steam Isolation Valve - Closure < 0.04

7. Drywell Pressure - High N/A

8. Scram Discharge Volume Water Level - High

a. Transmitter N/A

b. Float Switch N/A

9. Turbine Stop Valve Closure < 0.04

10. Turbine Control Valve Fast Closure, Trip < 0.05#

Oil Pressure - Low

11. Reactor Mode Switch - Shutdown Position N/A

12. Manual Scram N/A TABLE 13 NOTES

Neutron detectors are exempt from response time testing. Response time shall be measured from the detector output or from the input of the first electronic component in the channel.

- Not including a simulated thermal power time constant specified in the COLR.

- - Channel sensors are exempt from periodic response time testing.

Measured from start of turbine control valve fast closure. Page 20 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 14 END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) SYSTEM INSTRUMENTATION RESPONSE TIME LIMITS TRIP FUNCTION RESPONSE TIME (msec)

1. Turbine Stop Valve Closure < 140

2. Turbine Control Valve Fast Closure, Trip < 140 Oil Pressure - Low Page 21 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 15 MAIN STEAM LINE ISOLATION INSTRUMENTATION RESPONSE TIME LIMITS TRIP FUNCTION RESPONSE TIME (Seconds)

1. MAIN STEAM LINE ISOLATION

a. Reactor Vessel Water Level - Low Low Low, Level 1 < 1.0*

b. Main Steam Line Pressure - Low < 1.0*

c. Main Steam Line Flow - High < 0.5*

d. Condenser Vacuum - Low N/A

e. Main Steam Tunnel Temperature - High N/A

f. Main Steam Line Turbine Building Temperature - High N/A

g. Manual Initiation N/A TABLE 15 NOTES

Response time for MSIV's only, no diesel generator delays assumed. Channel sensors are exempt from periodic response time testing. Page 22 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 16 SETPOINT FOR THE CONTROL ROOM VENTILATION RADIATION MONITOR CHANNELS TRIP FUNCTION ACTUAL TRIP SETPOINT

1. MAIN CONTROL ROOM AIR INTAKE RADIATION - HIGH

a. Transmitter, Indicating 1RIXPR009A < 10 mR/hr 1RIXPR009B < 10 mR/hr 1RIXPR009C < 10 mR/hr 1RIXPR009D < 10 mR/hr Page 23 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 17 NOMINAL TRIP SETPOINTS TRIP FUNCTION NOMINAL TRIP SETPOINT (NTSP) CALCULATION (a)

Table 1, Function 6:

Main Steam Line Isolation Valve - Closure 8.6 % IP-C-0075 Table 5, Function 1 a:

Reactor Vessel Water Level -

Low Low Low, Level 1 -146.02 inches* IP-C-0073 Table 5, Function 1d:

Reactor Vessel Pressure - Low (Injection Permissive) 459.0 psig (lower)/ 489.0 psig (upper) 462.0 psig (lower)/ 486.0 psig (upper) IP-C-0062##

Table 5, Function 2a:

Reactor Vessel Water Level -

Low Low Low, Level 1 -146.02 inches* IP-C-0073 Table 5, Function 2d:

Reactor Vessel Pressure - Low (Injection Permissive) 459.0 psig (lower)/ 489.0 psig (upper) 462.0 psig (lower)/ 486.0 psig (upper) IP-C-0062###

Table 5, Function 3a:

Reactor Vessel Water Level -

Low Low, Level 2 -46.02 inches* IP-C-0094 Table 5, Function 3c:

Reactor Vessel Water Level -

High, Level 8 53.4 inches* IP-C-0094 Table 5, Function 3d:

RCIC Storage Tank Level -

Low 3.18 inches** IP-C-0061 Table 5, Function 3e:

Suppression Pool Water Level -

High 9.95 inches*** IP-C-0087 Table 5, Function 4a:

Reactor Vessel Water Level -

Low Low Low, Level 1 -146.02 inches* IP-C-0073 Table 5, Function 4e:

LPCS Pump Discharge Pressure -

High 126.6 psig (lower)/ 174.7 psig (upper) IP-C-0065 Page 24 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

TRIP SETPOINT AND RESPONSE TIME TABLES TABLE 17 NOMINAL TRIP SETPOINTS (continued)

TRIP FUNCTION NOMINAL TRIP SETPOINT (NTSP) CALCULATION (a)

Table 5, Function 4f:

LPCI Pump A Discharge Pressure -

High 116.6 psig (lower)/ 133.4 psig (upper) IP-C-0064#

Table 5, Function 5a:

Reactor Vessel Water Level -

Low Low Low, Level 1 -146.02 inches* IP-C-0073 Table 5, Function 5e:

LPCI Pumps B and C Discharge Pressure -

High 116.6 psig (lower)/ 133.4 psig (upper) IP-C-0064#

Relief and Low Low Set (LLS) Function:

a. Relief Function Low: 1109 psig Medium: 1119 psig High: 1129 psig IP-C-0077

b. LLS Function Low: 1035 psig Medium: 1075 psig High: 1115 psig IP-C-0077 Notes:

(a) The referenced calculation was completed using Engineering Standard CI-01.00, Instrument Setpoint Calculation Methodology. The referenced calculation determines the Nominal Trip Setpoints, the As-Found Tolerances and the As-Left Tolerances.

Instrument zero is 520.62 inches above Reactor Vessel zero.

- Instrument zero is elevation 739 ft. 10-3/4 inches msl.

- - Instrument zero is elevation 731 ft. 5 inches msl.

Transmitters: 1E12N055A, B, C; 1E12N056A, B, C

1. Transmitters: 1B21N078A; 1B21N697E 1B21N097A, 1B21N697A

1. 1. Transmitters: 1B21N078B; 1B21N697F 1B21N097B, 1B21N697B Page 25 Rev. 72 December 2011

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION VALVE NO. BYPASS DIRECTION SYSTEM(S) AFFECTED 1B21-F016 Continuous Close Nuclear Boiler 1B21-F019 Continuous Close Nuclear Boiler 1B21-F065A Continuous Open/Close Nuclear Boiler 1B21-F065B Continuous Open/Close Nuclear Boiler 1B21-F067A Continuous Close Nuclear Boiler 1B21-F067B Continuous Close Nuclear Boiler 1B21-F067C Continuous Close Nuclear Boiler 1B21-F067D Continuous Close Nuclear Boiler 1CC049 Continuous Close Component Cooling Water 1CC050 Continuous Close Component Cooling Water 1CC053 Continuous Close Component Cooling Water 1CC054 Continuous Close Component Cooling Water 1CC057 Continuous Close Component Cooling Water 1CC060 Continuous Close Component Cooling Water 1CC065 Continuous Close Component Cooling Water 1CC067 Continuous Close Component Cooling Water 1CC068 Continuous Close Component Cooling Water 1CC070 Continuous Close Component Cooling Water 1CC075A Continuous Close Component Cooling Water 1CC075B Continuous Close Component Cooling Water 1CC076A Continuous Close Component Cooling Water 1CC076B Continuous Close Component Cooling Water 1CC127 Continuous Close Component Cooling Water 1CC128 Continuous Close Component Cooling Water 1CY016 Continuous Close Cycled Condensate 1CY017 Continuous Close Cycled Condensate 1C41-F001A Continuous Open Standby Liquid Control 1C41-F001B Continuous Open Standby Liquid Control 1E12-F003A Continuous Open Residual Heat Removal 1E12-F003B Continuous Open Residual Heat Removal 1E12-F004A Continuous Open/Close Residual Heat Removal 1E12-F004B Continuous Open/Close Residual Heat Removal 1E12-F006A Continuous Open/Close Residual Heat Removal 1E12-F006B Continuous Open/Close Residual Heat Removal Note: This table presents the respective valve's overload bypass design direction(s). The "DIRECTION" should NOT be used to identify the respective valve's Design Basis Safety Function Direction. Valves' thermal overload protection may be bypassed in more than the Safety Function Direction. Refer to ORM section 2.5.2 for criteria regarding thermal overload protection. Page 1 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION VALVE NO. BYPASS DIRECTION SYSTEM(S) AFFECTED 1E12-F008 Continuous Open/Close Residual Heat Removal 1E12-F009 Continuous Close Residual Heat Removal 1E12-F014A Continuous Open/Close Residual Heat Removal 1E12-F014B Continuous Open/Close Residual Heat Removal 1E12-F021 Continuous Close Residual Heat Removal 1E12-F023 Continuous Open/Close Residual Heat Removal 1E12-F024A Continuous Open/Close Residual Heat Removal 1E12-F024B Continuous Open/Close Residual Heat Removal 1E12-F027A Continuous Open/Close Residual Heat Removal 1E12-F027B Continuous Open/Close Residual Heat Removal 1E12-F028A Continuous Open/Close Residual Heat Removal 1E12-F028B Continuous Open/Close Residual Heat Removal 1E12-F037A Continuous Open/Close Residual Heat Removal 1E12-F037B Continuous Open/Close Residual Heat Removal 1E12-F040 Continuous Close Residual Heat Removal 1E12-F042A Continuous Open/Close Residual Heat Removal 1E12-F042B Continuous Open/Close Residual Heat Removal 1E12-F042C Continuous Open/Close Residual Heat Removal 1E12-F047A Continuous Open Residual Heat Removal 1E12-F047B Continuous Open Residual Heat Removal 1E12-F048A Continuous Open/Close Residual Heat Removal 1E12-F048B Continuous Open/Close Residual Heat Removal 1E12-F049 Continuous Close Residual Heat Removal 1E12-F053A Continuous Open/Close Residual Heat Removal 1E12-F053B Continuous Open/Close Residual Heat Removal 1E12-F064A Continuous Open/Close Residual Heat Removal 1E12-F064C Continuous Open/Close Residual Heat Removal 1E12-F064B Continuous Open/Close Residual Heat Removal 1E12-F068A Continuous Open Residual Heat Removal 1E12-F068B Continuous Open Residual Heat Removal 1E12-F094 Continuous Open/Close Residual Heat Removal 1E12-F096 Continuous Open/Close Residual Heat Removal 1E12-F105 Continuous Open/Close Residual Heat Removal 1E12-F496 Continuous Open/Close Residual Heat Removal 1E12-F497 Continuous Open/Close Residual Heat Removal 1E21-F001 Continuous Open/Close Low Pressure Core Spray 1E21-F005 Continuous Open/Close Low Pressure Core Spray 1E21-F011 Continuous Open/Close Low Pressure Core Spray Note: This table presents the respective valve's overload bypass design direction(s). The "DIRECTION" should NOT be used to identify the respective valve's Design Basis Safety Function Direction. Valves' thermal overload protection may be bypassed in more than the Safety Function Direction. Refer to ORM section 2.5.2 for criteria regarding thermal overload protection. Page 2 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION VALVE NO. BYPASS DIRECTION SYSTEM(S) AFFECTED 1E21-F012 Continuous Close Low Pressure Core Spray 1E22-F001 Continuous Open/Close High Pressure Core Spray 1E22-F004 Continuous Open/Close High Pressure Core Spray 1E22-F010 Continuous Close High Pressure Core Spray 1E22-F011 Continuous Close High Pressure Core Spray 1E22-F012 Continuous Open/Close High Pressure Core Spray 1E22-F015 Continuous Open/Close High Pressure Core Spray 1E22-F023 Continuous Close High Pressure Core Spray 1E51-F010 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F013 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F019 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F022 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F031 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F045 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F046 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F059 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F063 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F064 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F068 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F076 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F077 Continuous Open/Close Reactor Core Isolation Cooling 1E51-F078 Continuous Open/Close Reactor Core Isolation Cooling 1E51-C002E Continuous Open/Close Reactor Core Isolation Cooling 1FC007 Continuous Close Fuel Pool Cooling & Cleanup 1FC008 Continuous Close Fuel Pool Cooling & Cleanup 1FC011A Continuous Open/Close Fuel Pool Cooling & Cleanup 1FC011B Continuous Open/Close Fuel Pool Cooling & Cleanup Note: This table presents the respective valve's overload bypass design direction(s). The "DIRECTION" should NOT be used to identify the respective valve's Design Basis Safety Function Direction. Valves' thermal overload protection may be bypassed in more than the Safety Function Direction. Refer to ORM section 2.5.2 for criteria regarding thermal overload protection. Page 3 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION VALVE NO. BYPASS DIRECTION SYSTEM(S) AFFECTED 1FC015A Continuous Open/Close Fuel Pool Cooling & Cleanup 1FC015B Continuous Open/Close Fuel Pool Cooling & Cleanup 1FC016A Continuous Close Fuel Pool Cooling & Cleanup 1FC016B Continuous Close Fuel Pool Cooling & Cleanup 1FC024A Continuous Close Fuel Pool Cooling & Cleanup 1FC024B Continuous Close Fuel Pool Cooling & Cleanup 1FC026A Continuous Open/Close Fuel Pool Cooling & Cleanup 1FC026B Continuous Open/Close Fuel Pool Cooling & Cleanup 1FC036 Continuous Close Fuel Pool Cooling & Cleanup 1FC037 Continuous Close Fuel Pool Cooling & Cleanup 1FP050 Continuous Close Fire Protection 1FP052 Continuous Close Fire Protection 1FP053 Continuous Close Fire Protection 1FP092 Continuous Close Fire Protection 1G33-F001 Continuous Close Reactor Water Cleanup 1G33-F004 Continuous Close Reactor Water Cleanup 1G33-F028 Continuous Close Reactor Water Cleanup 1G33-F034 Continuous Close Reactor Water Cleanup 1G33-F039 Continuous Close Reactor Water Cleanup 1G33-F040 Continuous Close Reactor Water Cleanup 1G33-F053 Continuous Close Reactor Water Cleanup 1G33-F054 Continuous Close Reactor Water Cleanup 1HG001 Continuous Open/Close H2 Recombining 1HG004 Continuous Open/Close H2 Recombining 1HG005 Continuous Open/Close H2 Recombining 1HG008 Continuous Open/Close H2 Recombining 1HG009A Continuous Open/Close H2 Recombining 1HG009B Continuous Open/Close H2 Recombining 1IA012A Continuous Open/Close Instrument Air 1IA012B Continuous Open/Close Instrument Air 1IA013A Continuous Open/Close Instrument Air 1IA013B Continuous Open/Close Instrument Air OMC009 Continuous Close Make Up Condensate Storage OMC010 Continuous Close Make Up Condensate Storage 1SF001 Continuous Close Suppression Pool Cleanup 1SF002 Continuous Close Suppression Pool Cleanup 1SF004 Continuous Close Suppression Pool Cleanup 1SM001A Continuous Open Suppression Pool Makeup 1SM001B Continuous Open Suppression Pool Makeup 1SM002A Continuous Open Suppression Pool Makeup 1SM002B Continuous Open Suppression Pool Makeup 1SX003A Continuous Open Shutdown Service Water 1SX003B Continuous Open Shutdown Service Water 1SX003C Continuous Open Shutdown Service Water Note: This table presents the respective valve's overload bypass design direction(s). The "DIRECTION" should NOT be used to identify the respective valve's Design Basis Safety Function Direction. Valves' thermal overload protection may be bypassed in more than the Safety Function Direction. Refer to ORM section 2.5.2 for criteria regarding thermal overload protection. Page 4 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION VALVE NO. BYPASS DIRECTION SYSTEM(S) AFFECTED 1SX004A Continuous Open Shutdown Service Water 1SX004B Continuous Open Shutdown Service Water 1SX004C Continuous Open Shutdown Service Water 1SX006C Continuous Open Shutdown Service Water 1SX008A Continuous Open/Close Shutdown Service Water 1SX008B Continuous Open/Close Shutdown Service Water 1SX008C Continuous Open/Close Shutdown Service Water 1SX011A Continuous Open/Close Shutdown Service Water 1SX011B Continuous Open/Close Shutdown Service Water 1SX012A Continuous Open/Close Shutdown Service Water 1SX012B Continuous Open/Close Shutdown Service Water 1SX013D Continuous Open/Close Shutdown Service Water 1SX013E Continuous Open/Close Shutdown Service Water 1SX013F Continuous Open/Close Shutdown Service Water 1SX014A Continuous Close Shutdown Service Water 1SX014B Continuous Close Shutdown Service Water 1SX014C Continuous Close Shutdown Service Water 1SX016A Continuous Open/Close Shutdown Service Water 1SX016B Continuous Open/Close Shutdown Service Water 1SX017A Continuous Open/Close Shutdown Service Water 1SX017B Continuous Open/Close Shutdown Service Water 1SX020A Continuous Close Shutdown Service Water 1SX020B Continuous Close Shutdown Service Water 1SX062A Continuous Open/Close Shutdown Service Water 1SX062B Continuous Open/Close Shutdown Service Water 1SX063A Continuous Open Shutdown Service Water 1SX063B Continuous Open Shutdown Service Water 1SX071A Continuous Open/Close Shutdown Service Water 1SX071B Continuous Open/Close Shutdown Service Water 1SX073A Continuous Open/Close Shutdown Service Water 1SX073B Continuous Open/Close Shutdown Service Water 1SX074A Continuous Open/Close Shutdown Service Water 1SX074B Continuous Open/Close Shutdown Service Water 1SX076A Continuous Open/Close Shutdown Service Water 1SX076B Continuous Open/Close Shutdown Service Water 1SX082A Continuous Close Shutdown Service Water 1SX082B Continuous Close Shutdown Service Water 1SX095A Continuous Open Shutdown Service Water 1SX095B Continuous Open Shutdown Service Water Note: This table presents the respective valve's overload bypass design direction(s). The "DIRECTION" should NOT be used to identify the respective valve's Design Basis Safety Function Direction. Valves' thermal overload protection may be bypassed in more than the Safety Function Direction. Refer to ORM section 2.5.2 for criteria regarding thermal overload protection. Page 5 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION VALVE NO. BYPASS DIRECTION SYSTEM(S) AFFECTED 1SX105A Continuous Open/Close Shutdown Service Water 1SX105B Continuous Open/Close Shutdown Service Water 1SX107A Continuous Open/Close Shutdown Service Water 1SX107B Continuous Open/Close Shutdown Service Water 1VP004A Continuous Close Drywell Cooling - Plant Chilled Water 1VP004B Continuous Close Drywell Cooling - Plant Chilled Water 1VP005A Continuous Close Drywell Cooling - Plant Chilled Water 1VP005B Continuous Close Drywell Cooling - Plant Chilled Water 1VP014A Continuous Close Drywell Cooling - Plant Chilled Water 1VP014B Continuous Close Drywell Cooling - Plant Chilled Water 1VP015A Continuous Close Drywell Cooling - Plant Chilled Water 1VP015B Continuous Close Drywell Cooling - Plant Chilled Water 1VQ006A Continuous Close Drywell Purge - Containment HVAC 1VQ006B Continuous Close Drywell Purge - Containment HVAC 1VR002A Continuous Close Drywell Purge - Containment HVAC 1VR002B Continuous Close Drywell Purge - Containment HVAC 1WO001A Continuous Close Drywell Cooling - Plant Chilled Water 1WO001B Continuous Close Drywell Cooling - Plant Chilled Water 1WO002A Continuous Close Drywell Cooling - Plant Chilled Water 1WO002B Continuous Close Drywell Cooling - Plant Chilled Water 1WO551A Continuous Close Drywell Cooling - Plant Chilled Water 1WO551B Continuous Close Drywell Cooling - Plant Chilled Water 1WO552A Continuous Close Drywell Cooling - Plant Chilled Water 1WO552B Continuous Close Drywell Cooling - Plant Chilled Water Note: This table presents the respective valve's overload bypass design direction(s). The "DIRECTION" should NOT be used to identify the respective valve's Design Basis Safety Function Direction. Valves' thermal overload protection may be bypassed in more than the Safety Function Direction. Refer to ORM section 2.5.2 for criteria regarding thermal overload protection. Page 6 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

1. Automatic Isolation Valves

1) Main Steam Line C 5 1,2,3 No 9.0 1B21-F022C C,D,E,G 3-5 H,J,U,R,X 1B21-F028C C,D,E,G, 3-5 H,J,U,R,X 1B21-F067C C,D,E,G, 14 H,J,U,R,X

2) Main Steam Line A 6 1,2,3 No 9.0 1B21-F022A C,D,E,G 3-5 H,J,U,R,X 1B21-F028A C,D,E,G, 3-5 H,J,U,R,X 1B21-F067A C,D,E,G, 14 H,J,U,R,X

3) Main Steam Line D 7 1,2,3 No 9.0 1B21-F022D C,D,E,G 3-5 H,J,U,R,X 1B21-F028D C,D,E,G, 3-5 H,J,U,R,X 1B21-F067D C,D,E,G, 14 H,J,U,R,X Page 1 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

4) Main Steam Line B 8 1,2,3 No 9.0 1B21-F022B C,D,E,G, 3-5 H,J,U,R,X 1B21-F028B C,D,E,G, 3-5 H,J,U,R,X 1B21-F067B C,D,E,G 14 H,J,U,R,X

5) Feedwater/RHR Line A 9 1,2,3 65 No 9.9 1E12-F053A A,T,X,R

6) Feedwater/RHR Line B 10 1,2,3 65 No 9.9 1E12-F053B A,T,X,R

7) RHR Shutdown Cooling 14 1,2,3,## No 9.0 1E12-F008 A,T,X,R 53 1E12-F009 A,T,X,R 53

8) RHR A To Fuel Pool 15 1,2,3 No 9.0 Cooling 1E12-F037A (i) A,T,X,R 120 Page 2 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

9) RHR B To Fuel Pool 16 1,2,3 No 9.0 Cooling 1E12-F037B (i) A,T,L,R 120

10) RHR A/LPCS Test Line 18 1,2,3 No 9.9 1E12-F024A L,U,(j) 45 1E21-F012 L,U,(j) 90

11) RHR C Test Line 19 1,2,3 No 9.9 1E12-F021 L,U,(j) 123

12) RHR B Test Line 20 1,2,3 No 9.9 1E12-F024B L,U,(j) 45

13) RCIC Suction 28 1,2,3 No 9.9 1E51-F031 V,X,B,R,E,(e) 48

14) HPCS Test Line 33 1,2,3 No 9.9 1E22-F023 B, L 68 Page 3 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

15) Supp. Pool Cleanup 34 1,2,3, # Yes 9.9 Suction 1SF004 B,L,R 84

16) RCIC 41/44 1,2,3, # Yes 9.0 1E51-F077 V.L,(c) 21

17) RHR Head Spray 42 1,2,3 No 9.0 1E12-F023 A,T,X,R 39

18) RCIC Steam Supply 43 1,2,3, # Yes 9.0 1E51-F063 V,E,X 41 1E51-F064 V,E,R,B,X,(e) 41 1E51-F076 V,E,X 14

19) RCIC Turb Vac Bkr 44 1,2,3, # Yes 9.0 Line 1E51-F078 V,L,(c) 27 Page 4 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

20) Main Steam Drain Line 45 1,2,3, #(f) Yes 9.0 1B21-F016 C,D,E,G,H,J, 50 U,X,R 1B21-F019 C,D,E,G,H,J U,X,R 50

21) Comp. Cooling Water 46 1,2,3, # Yes 9.0 Supply 1CC049 B,L,R 84 1CC050 B,L,R 45 1CC127 B,L,R 64

22) Comp. Cooling Water 47 1,2,3, # Yes 9.0 Return 1CC053 B,L,R 45 1CC054 B,L,R 84 1CC060 B,L,R 64

23) Breathing Air 49 1,2,3, # Yes 9.0 0RA026 (i) B,L,R NA 0RA027 (i) B,L,R NA

24) Make-up Condensate 50 1,2,3, # Yes 9.0 0MC009 B,L,R 58 0MC010 B,L,R 58 Page 5 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

25) Fuel Pool Cool/Cleanup 52 1,2,3 No 9.0 Supply 1FC036 B,L,R 75 1FC037 B,L,R 75

26) Fuel Pool Cool/Cleanup 53 1,2,3 No 9.0 Return 1FC007 B,L,R 66 1FC008 B,L,R 66

27) Fire Protection 56 1,2,3, # Yes 9.0 1FP052 B,L,R 87

28) Instrument Air Supply 57 1,2,3, # Yes 9.0 1IA005 U 36 1IA006 U 36

29) Instrument Air Bottles 58 1,2,3, # Yes 9.0 1IA012B L,B,R 25

30) Service Air Supply 59 1,2,3, # Yes 9.0 1SA030 B,L,R 16 1SA029 B,L,R 16 Page 6 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

31) RWCU Suction Line 60 1,2,3 No 9.0 1G33-F001 B,N,1,E,X,R,6,7 20 1G33-F004 B,N,1,E,X,R,6,7 20

32) RWCU Return to Filter 61 1,2,3 No 9.0 1G33-F053 B,N,1,E,X,R,7 21 1G33-F054 B,N,1,E,X,R,7 21

33) Hydrogen Recombiner 62 1,2,3, # Yes 9.0 Supply 1HG008 B,L,R 117

34) RWCU To RHR/FW 64 1,2,3 No 9.0 1G33-F040 B,N,1,E,X,R,7 21 1G33-F039 B,N,1,E,X,R,7 21

35) RWCU Transfer to 65 1,2,3, # Yes 9.0 Radwaste 1WX019 B,L,R 2 1WX020 B,L,R 2 Page 7 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

36) Process Sampling 68 1,2,3, # NA Yes 9.0 1PS016 B,L,R 1PS017 B,L,R 1PS022 B,L,R 1PS023 B,L,R 1PS034 B,L,R 1PS035 B,L,R 1PS055 B,L,R 1PS056 B,L,R 1PS069 B,L,R 1PS070 B,L,R

37) DW/Cont. Equip Drain 69 1,2,3 No 9.0 1RE021 B,L,R 16 1RE022 B,L,R 16

38) DW/Cont. Floor Drain 70 1,2,3 No 9.0 1RF021 B,L,R 16 1RF022 B,L,R 16

39) Hydrogen Recombiner 71 1,2,3, # Yes 9.0 Supply 1HG001 B,L,R 117

40) Hydrogen Recombiner 72 1,2,3 # Yes 9.0 Return 1HG004 B,L,R 117 Page 8 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

41) Deleted

42) Supp. Pool Cleanup 79 1,2,3 No 9.9 Return 1SF001 B,L,R 114 1SF002 B,L,R 126

43) Fire Protection 81 1,2,3, # Yes 9.0 1FP050 B,L,R 58 1FP092 B,L,R 58

44) Fire Protection 82 1,2,3, # Yes 9.0 1FP053 B,L,R 68

45) Cycle Condensate 85 1,2,3, # Yes 9.0 1CY016 B,L,R 75 1CY017 B,L,R 75

46) RWCU Letdown 86 1,2,3, # Yes 9.0 1G33-F028 B,N,1,E,X,R,7 24 1G33-F034 B,N,1,E,X,R,7 24 Page 9 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

47) Deleted

48) Containment HVAC 101 9.0 Supply 1VR001A(i) B,L,M,Z,5,R 1, 2, 3, # 4 Yes 1VR001B(i) B,L,M,Z,5,R 1, 2, 3, # 4 Yes 1VR002A P 1(g),2(g),3(g) 10 No 1VR002B P 1(g),2(g),3(g), # 10 Yes

49) Containment HVAC 102 Yes 9.0 Exhaust 1VQ004A(i) B,L,M,Z,5,R 1,2,3, # 6 1VQ004B(i) B,L,M,Z,5,R 1,2,3, # 6 (g) (g) (g) 1VQ006A P 1 ,2 ,3 , # 10 1VQ006B P 1(g),2(g),3(g), # 10

50) Plant Chilled 103 1,2,3, # Yes 9.0 Water Supply 1WO001A L,U,(j) 44 1WO001B L,U,(j) 44

51) Plant Chilled 104 1,2,3, # Yes 9.0 Water Return 1WO002A L,U,(j) 44 1WO002B L,U,(j) 44 Page 10 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

52) Containment Bldg. 106 1,2,3, # Yes 9.0 HVAC 1VR007B B,L,M,Z,5,R 6 1VR007A B,L,M,Z,5,R 6

53) DW Chilled Water 107 1,2,3, # Yes 9.0 Supply 1VP004B L,U,(j) 84 1VP005B L,U,(j) 84

54) DW Chilled Water 108 Yes 9.0 Return 1VP014B L,U,(j) 1,2,3, # 84 1VP015B L,U,(j) 84

55) DW Chilled Water 109 Yes 9.0 Supply 1VP004A L,U,(j) 1,2,3, # 84 1VP005A L,U,(j) 84

56) DW Chilled Water 110 1,2,3, # Yes 9.0 Return 1VP014A L.U,(j) 84 1VP015A L,U,(j) 84

57) Containment Bldg. 113 1,2,3, # Yes 9.0 HVAC 1VR006A B,L,M,Z,5,R 6 1VR006B B,L,M,Z,5,R 6 Page 11 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

58) Cont. Monit. 153 1,2,3 NA No 9.0 1CM022 B,L,R 1CM023 B,L,R 1CM025 B,L,R 1CM026 B,L,R

59) Hydrogen Recombiner 166 1,2,3, # 117 Yes 9.0 Supply 1HG005 B,L,R

60) Containment HVAC 169 1,2,3, # NA Yes 9.0 1VR035 B,L,M,Z,5,R 1VR036 B,L,M,Z,5,R 1VR040 B,L,M,Z,5,R 1VR041 B,L,M,Z,5,R

61) Cont. Monit 173 1,2,3 NA No 9.0 1CM048 B,L,R 1CM047 B,L,R 1CM011 B,L,R 1CM012 B,L,R

62) Instrument Air Bottles 206 1,2,3,# 25 Yes 9.0 1IA013B B,L,R

63) Process Sampling 210 1,2,3,# NA Yes 9.0 1PS038 B,L,R 1PS037 B,L,R Page 12 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 1 . Automatic Isolation Valves (Continued)

63) Process Sampling (continued) 1PS004 B,L,R 1PS005 B,L,R 1PS010 B,L,R 1PS009 B,L,R 1PS031 B,L,R 1PS032 B,L,R

2. Manual Isolation Valves

1) RHR/LPCI A 15 NA 1,2,3 NA No 9.0 1E12-F044A

2) RHR/LPCI B Injection 16 NA 1,2,3 NA No 9.0 1E12-F044B

3) Containment 152 NA 1,2,3 NA No 9.0 Monitoring 1CM080A 1CM080B 1CM080C 1CM081A 1CM081B 1CM081C Page 13 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a) 2 . Manual Isolation Valves (continued)

4) RHR A/LPCS Test Line 18 NA 1,2,3 NA No 9.9 1E12-F011A

5) RHR B Test Line 20 NA 1,2,3 NA No 9.9 1E12-F011B

6) Fire Protection 56 NA 1,2,3, # NA Yes 9.0 1FP051

7) SX To Recirc. Pump 78 NA 1,2,3 NA No 9.0 1CC074(j) (k) 1CC073 (j) (k)

8) Fire Protection 82 NA 1,2,3, # NA Yes 9.0 1FP054

9) SX From Recirc. Pump 88 NA 1,2,3 NA No 9.0 1CC071 (j) (k) 1CC072 (j) (k)

3. Test Connections, Vents, and Drains

1) Equipment Hatch 1 NA 1,2,3 NA No 9.0 1CM099

2) Fuel Handling 4 NA 1,2,3 NA No 9.0 1F42-F304A 1F42-F304B

3) Main Steam Line C 5 NA 1,2,3 NA No 9.0 1B21-F025C 1E32-F327C 1E32-F330A

4) Main Steam Line A 6 NA 1,2,3 NA No 9.0 1B21-F025A 1E32-F327A 1E32-F329A Page 14 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

5) Main Steam Line D 7 NA 1,2,3 NA No 9.0 1B21-F025D 1E32-F327D 1E32-F330C

6) Main Steam Line B 8 NA 1,2,3 NA No 9.0 1B21-F025B 1E32-F327B 1E32-F329C

7) Feedwater/RHR Line A 9 NA NA 9.9 1B21-F063A 1,2,3, # Yes 1B21-F030A 1,2,3 No 1B21-F518A 1,2,3 No 1E12-F058A 1,2,3 No 1E12-F349A 1,2,3 No 1E12-F507 1,2,3 No 1E12-F525A 1,2,3 No 1E12-F501A 1,2,3 No 1E12-F503A 1,2,3 No 1E12-F523A 1,2,3 No 1E12-F511A 1,2,3 No 1E12-F513 1,2,3 No Page 15 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

8) Feedwater/RHR Line B 10 NA NA 9.9 1B21-F063B 1,2,3,# Yes 1B21-F030B 1,2,3 No 1B21-F518B 1,2,3 No 1E12-F058B 1,2,3 No 1E12-F349B 1,2,3 No 1G33-F057 1,2,3 No 1E12-F505 1,2,3 No 1E12-F525B 1,2,3 No 1E12-F501B 1,2,3 No 1E12-F503B 1,2,3 No 1E12-F523B 1,2,3 No 1E12-F516A 1,2,3 No 1E12-F518 1,2,3 No

9) RHR A Suction 11 NA 1,2,3 NA No 9.9 1E12-F334A 1E12-F335A

10) RHR B Suction 12 NA 1,2,3 NA No 9.9 1E12-F334B 1E12-F335B

11) RHR C Suction 13 NA 1,2,3 NA No 9.9 1E12-F334C 1E12-F335C

12) RHR Shutdown 14 NA 1,2,3 NA No 9.0 Cooling 1E12-F001 Page 16 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

13) RHR/LPCI A Injection 15 NA 1,2,3 NA No 9.0 1E12-F107A 1E12-F331A 1E12-F329A

14) RHR/LPCI B Injection 16 NA 1,2,3 NA No 9.0 1E12-F107B 1E12-F331B 1E12-F329B

15) RHR/LPCI C Injection 17 NA 1,2,3 NA No 9.0 1E12-F056C

16) RHR A Test Line 18 NA 1,2,3 NA No 9.9 1E12-F365A 1E12-F366A 1E21-F346 1E21-F347 1E12-F414 1E12-F415 1E12-F418 1E12-F419 1E12-F420 1E12-F421

17) RHR C Test Line 19 NA 1,2,3 NA No 9.9 1E12-F353 1E12-F354 1E12-F428 1E12-F429 Page 17 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION TIME BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE (Seconds) PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

18) RHR B Test Line 20 NA 1,2,3 NA No 9.9 1E12-F365B 1E12-F366B 1E12-F426 1E12-F427

19) RHR HX 24 NA 1,2,3 NA No 9.9 1E12-F432A 1E12-F433A

20) RHR HX 26 NA 1,2,3 NA No 9.9 1E12-F432B 1E12-F433B

21) RCIC Pump Suction 28 NA 1,2,3 NA No 9.9 1E51-F336 1E51-F337

22) RCIC Suction Release 31 NA 1,2,3 NA No 9.9 Discharge 1E12-F436 1E12-F437

23) LPCS Pump Suction 32 NA 1,2,3 NA No 9.9 1E21-F331 1E21-F344

24) HPCS Test to Supp. 33 NA 1,2,3 NA No 9.9 Pool 1E22-F376

25) Supp. Pool Cleanup 34 NA 1,2,3 NA No 9.9 Pump Suction 1SF034 Page 18 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

26) HPCS Pump 35 NA 1,2,3 NA No 9.0 Discharge 1E22-F021

27) LPCS Pump 36 NA 1,2,3 NA No 9.0 Discharge 1E21-F013

28) RCIC 41 NA 1,2,3 NA No 9.9 1E51-F041

29) Head Spray 42 NA 1,2,3 NA No 9.0 1E51-F034 1E51-F391 1E12-F061

30) RCIC Turb Steam 43 NA 1,2,3 NA No 9.0 Supply 1E51-F399 1E51-F072 1E51-F401

31) RCIC Turb Vacuum 44 NA 1,2,3 NA No 9.0 Breaker 1E51-F080 1E51-F082 1E51-F375 1E51-F376 1E51-F083 Page 19 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

32) Main Steam Drain 45 NA 1,2,3 NA No 9.0 Line 1B21-F017

33) CCW Supply 46 NA NA 9.0 1CC164 1,2,3 No 1CC266 1,2,3, # Yes

34) CCW Return 47 NA 1,2,3 NA No 9.0 1CC165

35) Makeup Condensate 50 NA 1,2,3 NA No 9.0 1MC011

36) Fuel Pool 52 NA 1,2,3 NA No 9.0 Cool/Cleanup Supply 1FC180

37) Fuel Pool 53 NA 1,2,3 NA No 9.0 Cool/Cleanup Return 1FC181

38) Fire Protection 56 NA 1,2,3 NA No 9.0 1FP199

39) Instrument Air 57 NA 1,2,3 NA No 9.0 1IA039 Page 20 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

40) Service Air Line 59 NA 1,2,3 NA No 9.0 1SA046

41) RWCU Pump Suction 60 NA NA 9.0 1G33-F002 1,2,3 No

42) RWCU Return 61 NA 1,2,3 NA No 9.0 1G33-F061

43) Hydrogen 62 NA 1,2,3 NA No 9.0 Recombiner 1HG019

44) CRD Pump 63 NA 1,2,3 NA No 9.0 Discharge 1C11-F128

45) RWCU Return 64 NA 1,2,3 NA No 9.0 1G33-F055

46) Containment 67 NA 1,2,3 NA No 9.0 Pressurization (test penet.)

1SA129

47) Hydrogen 71 NA 1,2,3 NA No Recombiner 1HG016 9.0 1HG020 NA

48) Hydrogen 72 NA 1,2,3 NA No Recombiner 1HG017 9.0 1HG021 NA Page 21 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

49) RWCU Decon 74 NA 1,2,3 NA No 9.0 1G33-F428

50) SX To Recir. Pump 78 NA 1,2,3 NA No 9.0 1CC170

51) Supp. Pool Cleanup 79 NA 1,2,3 NA No 9.0 Return 1SF023

52) Fire Protection 81 NA 1,2,3 NA No 9.0 1FP201

53) Fire Protection 82 NA 1,2,3 NA No 9.0 1FP200

54) Cycle Condensate 85 NA 1,2,3 NA No 9.0 1CY019

55) RWCU Letdown 86 NA 1,2,3 NA No 9.0 1G33-F070

56) SX From Recir. 88 NA 1,2,3 NA No 9.0 Pump 1CC171

57) Containment HVAC 101 NA 1,2,3 NA No 9.0 Supply 1VR003 Page 22 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

58) Containment HVAC 102 NA 1,2,3 NA No 9.0 Return 1VQ007

59) Containment HVAC 106 NA 1,2,3 NA No 9.0 1VR011

60) Drywell Chilled 107 NA 1,2,3 NA No 9.0 Water 1VP044B 1VP077D

61) Drywell Chilled 108 NA 1,2,3 NA No 9.0 Water 1VP047B 1VP077B

62) Drywell Chilled 109 NA 1,2,3 NA No 9.0 Water 1VP044A 1VP077C

63) Drywell Chilled 110 NA 1,2,3 NA No 9.0 Water 1VP047A 1VP077A

64) Containment HVAC 113 NA 1,2,3 NA No 9.0 1VR012 Page 23 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections, Vents, and Drains (Continued)

65) Deleted

66) Drywell Pressure NA NA No 9.0 1CM076 151 1,2,3 1CM077 203

67) Reactor Pressure 151 NA 1,2,3 NA No 9.0 1CM072 1CM073

68) Reactor Pressure 160 NA 1,2,3 NA No 9.0 1CM074 1CM075

69) Hydrogen 166 NA 1,2,3 NA No 9.0 Recombiner 1HG018

70) Suppression Pool 177 NA 1,2,3 NA No 9.9 Level 1E51-F437A 1E51-F437B Page 24 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

3. Test Connections. Vents, and Drains (Continued)

71) Suppression Pool 179 NA 1,2,3 NA No 9.9 Level 1E22-F381A 1E22-F381B 1SM027A 1SM027B

72) Suppression Pool 181 NA 1,2,3 NA No 9.9 Level 1SM026A 1SM026B

73) Suppression Pool 183 NA 1,2,3 NA No 9.9 Level 1CM100A 1CM100B Page 25 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves

1) Main Steam Line C 5 NA 1,2,3 NA No 9.0 1E32-F001J

2) Main Steam Line A 6 NA 1,2,3 NA No 9.0 1E32-F001A

3) Main Steam Line D 7 NA 1,2,3 NA No 9.0 1E32-F001N

4) Main Steam Line B 8 NA 1,2,3 NA No 9.0 1E32-F001E

5) Feedwater/RHR Line 9 NA Note 1 A

1B21-F010A NA 1,2,3, # Yes 9.9 1B21-F065A NA 1,2,3, # Yes 1B21-F032A B,L,R 1,2,3, # Yes 1E12-F497 NA 1,2,3 No

6) Feedwater/RHR Line 10 NA Note 1 B

1B21-F010B NA 1,2,3, # Yes 9.9 1B21-F065B NA 1,2,3, # Yes 1B21-F032B B,L,R 1,2,3, # Yes 1E12-F496 NA 1,2,3 No

7) RHR A Suction Line 11 NA 1,2,3 NA No 9.9 1E12-F004A

8) RHR B Suction Line 12 NA 1,2,3 NA No 9.9 1E12-F004B Page 26 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

9) RHR C Suction Line 13 NA 1,2,3 NA No 9.9 1E12-F105

10) RHR/LPCI A 15 NA 1,2,3 NA No 9.0 Injection 1E12-F027A 1E12-F042A 1E12-F028A

11) RHR/LPCI B 16 NA 1,2,3 NA No 9.0 Injection 1E12-F027B 1E12-F042B 1E12-F028B

12) RHR/LPCI C 17 NA 1,2,3 NA No 9.0 Injection 1E12-F042C

13) RHR A/LPCS Test 18 NA 1,2,3 NA No 9.9 Line 1E21-F011 1E12-F064A

14) RHR C Test Line 19 NA 1,2,3 NA No 9.9 1E12-F064C

15) RHR B Test Line 20 NA 1,2,3 NA No 9.9 1E12-F064B

16) RHR A Suction 21 NA 1,2,3 NA No 9.9 Relief 1E12-F017A Page 27 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

17) RHR Shutdown Cool 23 NA 1,2,3 NA No NA Relief 1E12-F005

18) RHR A HX Relief 24 NA 1,2,3 NA No 9.9 Line 1E12-F055A (Setpoint Raised) 1E12-F112A

19) RHR B Suction 25 NA 1,2,3 NA No 9.9 Relief 1E12-F017B

20) RHR B HX Relief 26 NA 1,2,3 NA No 9.9 Line 1E12-F055B (Setpoint Raised) 1E12-F112B

21) RHR/LPCI B Inj. 16/27 NA 1,2,3 NA No 9.0 Relief 1E12-F025B

22) RHR C Suction 29 NA 1,2,3 NA No 9.9 Relief 1E12-F101

23) RHR/LPCI C Inj. 30 NA 1,2,3 NA No 9.9 Relief 1E12-F025C

24) RHR To RCIC 31 NA 1,2,3 NA No 9.9 Suction Relief 1E12-F036 Page 28 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

25) LPCS Suction Line 32 NA 1,2,3 NA No 9.9 1E21-F001

26) HPCS Test Line & 33 NA 1,2,3 NA No 9.9 Relief 1E22-F014 1E22-F035 1E22-F039 1E22-F012

27) HPCS Injection Line 35 NA 1,2,3 NA No 9.0 1E22-F004

28) LPCS Injection Line 36 NA 1,2,3 NA No 9.0 1E21-F005

29) HPCS Suction Line 37 NA 1,2,3 NA No 9.9 1E22-F015

30) LPCS Pump Relief 38 NA 1,2,3 NA No 9.9 Line 1E21-F018 1E21-F031

31) RCIC Min. Flow 40 NA 1,2,3 NA No Relief 1E51-F090 NA 1E51-F019 9.9 Page 29 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

32) RCIC Turbine NA 1,2,3 NA No 9.9 Exhaust 1E51-F068 41 1E51-F040 28/41

33) RCIC Head Spray 42 NA 1,2,3 NA No 9.0 1E51-F013

34) Deleted

35) Make-Up Condensate 50 NA 1,2,3, # NA Yes 9.0 1MC090

36) Instrument Air 57 NA 1,2,3 NA No 9.0 1IA175

37) Instrument Air 58 NA 1,2,3, # NA Yes 9.0 Bottles 1IA042B 1IA012A

38) CRD 63 NA 1,2,3, # NA Yes 1C11-F122 9.0 1C11-F083

39) RWCU Transfer to 65 NA 1,2,3, # NA Yes 9.0 Radwaste 1WX080 Page 30 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

40) RHR Flush Line 76 NA 1,2,3 NA No 9.9 1E12-F030

41) RHR/LPCI A Injec. 15/87 NA 1,2,3 NA No 9.0 Relief 1E12-F025A

42) NOT USED

43) DW Chilled Water 107 NA 1,2,3 NA No 9.0 Relief 1VP023B

44) DW Chilled Water 108 NA 1,2,3 NA No 9.0 Relief 1VP027B

45) DW Chilled Water 109 NA 1,2,3 NA No 9.0 Relief 1VP023A

46) DW Chilled Water 110 NA 1,2,3 NA No 9.0 1VP027A

47) Containment Press 150 NA 1,2,3 0.58 scfm < flow No NA

< 3 scfm (b2) 1CM003A(d)

48) Drywell Pressure 151 NA 1,2,3 0.58 scfm < flow No NA

< 3 scfm (b2) 1CM051(d) Page 31 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

49) Reactor Pressure 151 NA 1,2,3 flow 1.2 gpm No NA (b1) 1CM066(d)

50) Containment Bldg 156 NA 1,2,3 0.58 scfm < flow No NA HVAC < 3 scfm (b2) lVG056B(d)

51) Suppression Pool 157 NA 1,2,3 0.58 scfm < flow No NA Level < 3 scfm (b2) 1CM002A(d) 1CM003B(d)

52) Reactor Pressure 160 NA 1,2,3 flow 1.2 gpm No NA (b1) 1CM067(d)

53) Suppression Pool 164 NA 1,2,3 0.58 scfm < flow No NA Level < 3 scfm (b2) 1SM010(d)

54) Containment Bldg 165 NA 1,2,3 0.58 scfm < flow No NA HVAC < 3 scfm (b2) 1VR016A(d) 1VR016B(d) 1VR018A(d)

55) Containment Bldg. 167 NA 1,2,3 0.58 scfm < flow No NA HVAC < 3 scfm (b2) 1VG057B(d) Page 32 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

56) Containment Bldg. 168 NA 1,2,3 0.58 scfm < flow No NA HVAC < 3 scfm (b2) 1VR018B(d)

57) Suppression Pool 171 NA 1,2,3 0.58 scfm < flow No NA

< 3 scfm (b2) 1SM009(d)

58) Not Used

59) Suppression Pool 177 NA 1,2,3 flow < 1 gpm No NA Level (b2) 1E51-F377B(d)

60) Suppression Pool 179 NA 1,2,3 flow < 1 gpm No NA Level (b2) 1E22-F332(d) 1SM011(d)

61) HPCS 180 NA 1,2,3 0.58 scfm < flow No NA

< 3 scfm (b2) 1E22-F330(d)

62) Suppression Pool 181 NA 1,2,3 flow < 1 gpm No NA Level (b2) 1SM008(d)

63) Suppression Pool 183 NA 1,2,3 flow < 1 gpm No NA Level (b2) 1CM002B(d) Page 33 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES SECONDARY MAXIMUM CONTAINMENT ISOLATION BYPASS TEST VALVE PENETRATION ISOLATION APPLICABLE TIME PATH PRESSURE NUMBER NUMBER SIGNAL (h) MODES (Seconds) (Yes/No) psig (a)

4. Other Isolation Valves (Continued)

64) RCIC 200 NA 1,2,3 0.58 scfm < flow No NA

< 3 scfm (b2) 1E51-F377A(d)

65) Drywell Pressure 203 NA 1,2,3 0.58 scfm < flow No NA

< 3 scfm (b2) 1CM053(d)

66) Deleted

67) Deleted

68) Instrument Air 206 NA 1,2,3, # NA Yes 9.0 Bottles 1IA042A 1IA013A

69) Deleted Page 34 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES TABLE NOTATIONS (a) For test pressure = 9.0 psig, the valve(s) shall be pressurized using air or nitrogen, and for test pressure = 9.9 psig, the valve(s) shall be pressurized using water.

(b) Excess flow check valve actuation flow.

(b1) This excess flow check valve communicates with the reactor coolant pressure boundary. As such, it is tested per TS SR 3.6.1.3.12. See Bases SR 3.6.1.3.12.

(b2) This excess flow check valve does NOT communicate with the reactor coolant pressure boundary. The In-Service Testing (IST) program provides assurance of integrity in accordance with USAR Table 6.2-47. IST program testing is dependent on safety function as identified in the IST bases documents.

(c) Isolates on RCIC low steam line pressure only.

(d) Excess flow check valve.

(e) A manual isolation permissive is provided by the "B" signal for valves 1E51-F031 and 1E51-F064.

The manual isolation pushbutton must be depressed for these valves to close.

(f) Valves shall be closed to support Secondary Containment OPERABILITY.

(g) Valves shall be "sealed closed" under administrative control to assure that they cannot be inadvertently opened. Administrative control includes mechanical devices to seal or lock the valve closed, or to prevent power from being supplied to the valve operator. For valves supplied with keylock control switches, removal of the key in conjunction with tagging the control switches in the main control room in the closed position satisfies this requirement. Page 35 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

CONTAINMENT ISOLATION VALVES (h) Containment isolation trip signals are tabulated below:

Symbol Description A Reactor Vessel Water Level Low (Level 3)

B Reactor Vessel Water Level Low (Level 2)

C Deleted D Main Steam Line High Flow E Main Steam Tunnel Temp. High G Main Steam in Turbine Building Temp. High H Turbine Inlet Pressure Low J Condenser Vacuum Low L Drywell Pressure High M Containment Exhaust Duct High Rad.

N RWCU High Temp.

P Containment Pressure-High R CRVICS Manual Initiation Pushbuttons T RHR Heat Exchanger Rooms A, B High Temp.

U Reactor Water Level Low (Level 1)

V RCIC High Steam Line Space Temp.

RCIC Low Steam Line Pressure RCIC High Steam Flow High Turbine Exhaust Pressure RCIC Area High Temp.

X Permissively Interlocked with Other Equipment Z High Rad. in Containment Refueling Pool Exhaust Duct 1 RWCU Equipment High Differential Flow 5 Containment Purge Duct High Radiation 6 SLC Initiation 7 RWCU Isolation Manual Initiation (i) May be considered a manual valve as long as the valve is maintained closed by use of administrative control.

(j) This valve receives a closure signal upon manual initiation of the associated RHR division.

(k) The valves shall be "sealed closed" under administrative control to assure that they cannot be inadvertently opened. Administrative control includes mechanical devices to seal and lock the valve closed and prevent power from being supplied to the valve operator. The valves are considered manual valves as long as they are maintained closed by use of administrative control.

(1) Per Licensing Amendment 127 leakage through 1B21-F010A/B is not included in T.S. SR 3.6.1.3.11 limit.

The valves are tested IAW CPS Inservice Testing Program requirements.

(m) EC 371540 authorized installation of a blind coupling on the outboard side of penetration 116. Valves 1C41-F340B and 1C41-F341B are abandoned-in-place.

During movement of recently irradiated fuel assemblies in the primary or secondary containment and during operations with a potential for draining the reactor vessel.

1. In Modes 4 and 5 when the associated isolation instrumentation is required OPERABLE per Technical Specification LCO 3.3.6.1 Function 5.c. Page 36 Rev. 75 June 2012

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

DRYWELL ISOLATION VALVES DRYWELL ISOLATION VALVES System Penetration Valve(s) Operator Valve Isolation Number Type Type Signal RR Process Sampling 1MD-13 1B33-F019 AOV Globe B 1B33-F020 AOV Globe B Chilled Water for 1MD-53 1WO551A MOV Gate U,L drywell cooling coil 1WO551B MOV Gate U,L cabinets G & H 1WO552A MOV Gate U,L 1WO552B MOV Gate U,L Instrument Air 1MD-57 1IA007 AOV Gate U 1IA008 AOV Gate U Service Air 1MD-59 1SA031 AOV Gate B,L 1SA032 AOV Gate B,L Drywell Equipment 1MD-69 1RE019 AOV Gate B,L Drains, pump discharge 1RE020 AOV Gate B,L Drywell Floor Drains, 1MD-70 1RF019 AOV Gate B,L pump discharge 1RF020 AOV Gate B,L Drywell Purge Air inlet 1MD-101 1VQ001A AOD Butterfly B,L,M,Z,5 1VQ001B AOD Butterfly B,L,M,Z,5 Drywell Purge Air outlet 1MD-102 1VQ002 AOD Butterfly B,L,M,Z,5 1VQ003 AOD Butterfly B,L,M,Z,5 1VQ005 AOD Butterfly B,L,M,Z,5 Breathing Air 1MD-106 0RA028 AOV Gate B,L 0RA029 AOV Gate B,L Fire Protection 1MD-124 1FP078 MOV Gate B,L (note 1) 1FP079 MOV Gate B,L (note 1)

Condensate 1MD-125 1CY020 MOV Gate B,L (note 1)

Makeup/RHR 1CY021 MOV Gate B,L (note 1)

Leak Detection 1MD-182 1E31-F014 SOV Gate B,L 1E31-F015 SOV Gate B,L 1E31-F017 SOV Gate B,L 1E31-F018 SOV Gate B,L Page 1 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

DRYWELL ISOLATION VALVES DRYWELL ISOLATION VALVES (Continued)

System Penetration Valve(s) Operator Valve Isolation Signal Number Type Type Standby Liquid 1MD-4 1C41-F006 ----- Check -----

Control 1C41-F007 ----- Check -----

1C41-F336 ----- Check -----

1C41-F026 Manual Globe Locked Closed RR Pump Seal Purge 1MD-11 1B33-F013A ----- Check -----

"A" 1B33-F017A ----- Check -----

RR Pump Seal Purge 1MD-12 1B33-F013B ----- Check -----

"B" 1B33-F017B ----- Check -----

RR Process Sampling 1MD-13 1B33-F021 Manual Globe Closed/Capped RHR/LPCI "A" 1MD-15 1E12-F041A ----- Check -----

1E12-F301A AOV Gate NC/Open for test 1E12-F056A Manual Globe Locked Closed RHR/LPCI "B" 1MD-16 1E12-F041B ----- Check -----

1E12-F301B AOV Gate NC/Open for test 1E12-F056B Manual Globe Locked Closed 1E12-F456A Manual Globe Locked Closed 1E12-F373C Manual Globe Locked Closed RHR/LPCI "C" 1MD-17 1E12-F041C ----- Check -----

1E12-F301C AOV Gate NC/Open for test 1E12-F456B Manual Globe Locked Closed 1E12-F351 Manual Globe Locked Closed HPCS discharge to 1MD-35 1E22-F005 ----- Check -----

Reactor Pressure 1E22-F304 AOV Gate NC/Open for test Vessel 1E22-F366B Manual Globe Locked Closed LPCS discharge to 1MD-36 1E21-F006 ----- Check -----

Reactor Pressure 1E21-F358 Manual Globe Locked Closed Vessel 1E21-F340 AOV Gate NC/Open for test 1E21-F356A Manual Globe Locked Closed Chilled Water for 1MD-53 1WO557 Manual Globe Closed/Capped drywell cooling coil 1WO570A ----- Relief -----

cabinets G & H 1WO560 Manual Globe Closed/Capped 1WO570B ----- Relief -----

Drywell Vacuum 1MD-72 1HG010A ----- Check -----

Breakers 1HG011A ----- Check ----- Page 2 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

DRYWELL ISOLATION VALVES DRYWELL ISOLATION VALVES (Continued)

System Penetration Valve(s) Operator Valve Isolation Signal Number Type Type RHR 1MD-94 1E12-F073B MOV Globe Closed 1E12-F110B ----- Check -----

Dry well Purge Air 1MD-101 1VQ011 Manual Globe Closed/Capped inlet Dry well Purge Air 1MD-102 1VQ012 Manual Globe Closed/Capped outlet Drywell Vacuum 1MD-117 1HG010B ----- Check -----

Breakers 1HG011B ----- Check -----

Drywell Vacuum 1MD-119 1HG010D ----- Check -----

Breakers 1HG011D ----- Check -----

Drywell Vacuum 1MD-120 1HG010C ----- Check -----

Breakers 1HG011C ----- Check -----

Condensate 1MD-125 1E12-F073A MOV Globe Closed Makeup/RHR 1E12-F110A ----- Check -----

Leak Detection 1MD-182 1E31-F016 SOV Gate Failed Closed 1E31-F019 SOV Gate Failed Closed Table Legend AOD - Air Operated Damper AOV - Air Operated Valve HPCS - High Pressure Core Spray LPCI - Low Pressure Coolant Injection LPCS - Low Pressure Core Spray MOV - Motor Operated Valve NC - Normally Closed RHR - Residual Heat Removal RR - Reactor Recirculation SOV - Solenoid Operated Valve Table Note (1) Locked Shut and de-energized Isolation Signals Symbol Description B Reactor Vessel Water Level Low (Level 2)

L Drywell Pressure High M Containment Exhaust Duct High Radiation U Reactor Vessel Water Level Low (Level 1)

Z High Radiation in Containment Refueling Pool Exhaust Duct 5 Containment Purge Duct High Radiation Page 3 Rev. 69 December 2010

CPS OPERATIONAL REQUIREMENTS MANUAL (ORM)

SECONDARY CONTAINMENT ISOLATION VALVES Automatic Dampers Damper Description 1VF06Y Fuel Building Supply Inboard Isolation Damper 1VF07Y Fuel Building Exhaust Inboard Isolation Damper 1VF04Y Fuel Building Supply Outboard Isolation Damper 1VF09Y Fuel Building Exhaust Outboard Isolation Damper Manual Dampers Damper Description 0VG03YA Standby Gas Treatment System Train "A" Control Building Inlet Damper 0VG03YB Standby Gas Treatment System Train "B" Control Building Inlet Damper Page 1 Rev. 42 September 2004

RS-13-009, Operational Requirements Manual (Orm) 2013

Text

Reference:

References:

Navigation menu

RS-13-009, Operational Requirements Manual (Orm) 2013

Text

Reference:

References:

Navigation menu

Search