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CALLAWAY PLANT 1.3-1 Amendment No. 133 | CALLAWAY PLANT 1.3-1 Amendment No. 133 | ||
Completion Times 1.3 1.3 Completion Times DESCRIPTION a. Must exist concurrent with the first inoperability; and (continued) | Completion Times 1.3 1.3 Completion Times DESCRIPTION a. Must exist concurrent with the first inoperability; and (continued) | ||
: b. Must remain inoperable or not within limits after the first inoperability is resolved. | : b. Must remain inoperable or not within limits after the first inoperability is resolved. | ||
The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either. | The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either. | ||
: a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional | : a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours; or | ||
: b. The stated Completion Time as measured from discovery of the subsequent inoperability. | : b. The stated Completion Time as measured from discovery of the subsequent inoperability. | ||
The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications. | The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications. | ||
The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per | The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery. . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 1.3-2 Amendment No. 133 | CALLAWAY PLANT 1.3-2 Amendment No. 133 | ||
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Completion Times 1.3 1.3 Completion Times (continued) | Completion Times 1.3 1.3 Completion Times (continued) | ||
EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions. | EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions. | ||
EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMTIEON B. Required B.1 Be in MODE 3. | EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMTIEON B. Required B.1 Be in MODE 3. 6 hours Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered. | ||
The Required Actions of Condition B are to be in MODE 3 within | The Required Actions of Condition B are to be in MODE 3 within 6 hours AND in MODE 5 within 36 hours. A total of 6 hours is allowed for reaching MODE 3 and a total of 36 hours (not 42 hours) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours, the time allowed for reaching MODE 5 is the next 33 hours because the total time allowed for reaching MODE 5 is 36 hours. | ||
If Condition B is entered while in MODE 3, the time allowed for reaching MODE 5 is the next | If Condition B is entered while in MODE 3, the time allowed for reaching MODE 5 is the next 36 hours. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 1.3-3 Amendment No. 133 | CALLAWAY PLANT 1.3-3 Amendment No. 133 | ||
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Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued) | Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued) | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status. | ||
B. Required B.1 Be in MODE 3. | B. Required B.1 Be in MODE 3. 6 hours Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours When a pump is declared inoperable, Condition A is entered. If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated. | ||
When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered. | When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered. | ||
While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO'3.0.3 may be exited and operation continued in accordance with Condition A. | While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO'3.0.3 may be exited and operation continued in accordance with Condition A. | ||
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CALLAWAY PLANT 1.3-5 Amendment No. 133 | CALLAWAY PLANT 1.3-5 Amendment No. 133 | ||
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued) | Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued) | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore Function X 7 days Function X train to OPERABLE train status. AND inoperable. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore Function X 7 days Function X train to OPERABLE train status. AND inoperable. | ||
10 days from discovery of failure to meet the LCO B. One B.1 Restore Function Y | 10 days from discovery of failure to meet the LCO B. One B.1 Restore Function Y 72 hours Function Y train to OPERABLE train status. AND inoperable. | ||
10 days from discovery of failure to meet the LCO C. One C.1 Restore Function X | 10 days from discovery of failure to meet the LCO C. One C.1 Restore Function X 72 hours Function X train to OPERABLE train status. | ||
inoperable. | inoperable. | ||
OR AND C.2 Restore Function Y | OR AND C.2 Restore Function Y 72 hours One train to OPERABLE Function Y status. | ||
train inoperable. | train inoperable. | ||
(continued) | (continued) | ||
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Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued) | Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued) | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One or more A.1 Restore valve(s) to | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One or more A.1 Restore valve(s) to 4 hours valves OPERABLE status. | ||
inoperable. | inoperable. | ||
B. Required B.1 Be in MODE 3. | B. Required B.1 Be in MODE 3. 6 hours Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times. | ||
Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to | Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours provided this does not result in any subsequent valve being inoperable for > 4 hours. | ||
If the Completion Time of | If the Completion Time of 4 hours (including the extension) expires while one or more valves are still inoperable, Condition B is entered. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 1.3-8 Amendment No. 133 | CALLAWAY PLANT 1.3-8 Amendment No. 133 | ||
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Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued) | Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued) | ||
ACTIONS NOTE Separate Condition entry is allowed for each inoperable valve. | ACTIONS NOTE Separate Condition entry is allowed for each inoperable valve. | ||
CONDITION REQUIRED ACTION COMPLETION A. One or more A.1 Restore valve to | CONDITION REQUIRED ACTION COMPLETION A. One or more A.1 Restore valve to 4 hours valves OPERABLE status. | ||
inoperable. | inoperable. | ||
B. Required B.1 Be in MODE 3. | B. Required B.1 Be in MODE 3. 6 hours Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table. | ||
The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve. | The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve. | ||
(continued) | (continued) | ||
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If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve. | If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve. | ||
Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply. | Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply. | ||
EXAMPLE 1.3-6 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per inoperable. | EXAMPLE 1.3-6 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per inoperable. 8 hours OR A.2 Reduce THERMAL 8 hours POWER to I | ||
< 50% RTP. | < 50% RTP. | ||
B. Required B.1 Be in MODE 3. | B. Required B.1 Be in MODE 3. 6 hours Action and associated Completion Time not met. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 1.3-10 Amendment No. 135 MAR, 2 7 200 | CALLAWAY PLANT 1.3-10 Amendment No. 135 MAR, 2 7 200 | ||
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Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued) | Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued) | ||
Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8 hour interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2), | Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8 hour interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2), | ||
Condition B is entered. If Required Action A.2 is followed and the Completion Time of | Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours is not met, Condition B is entered. | ||
If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A. | If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 1.3-1 1 Amendment No. 133 | CALLAWAY PLANT 1.3-1 1 Amendment No. 133 | ||
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued) | Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued) | ||
ACTIONS CONDITION REQUIRED ACTION C IMPMETION A. One A.1 Verify affected 1 hour subsystem subsystem isolated. | ACTIONS CONDITION REQUIRED ACTION C IMPMETION A. One A.1 Verify affected 1 hour subsystem subsystem isolated. | ||
inoperable. AND Once per | inoperable. AND Once per 8 hours thereafter AND A.2 Restore subsystem to 72 hours OPERABLE status. | ||
B. Required B.1 Be in MODE 3. | B. Required B.1 Be in MODE 3. 6 hours Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours Required Action A.1 has two Completion Times. The 1 hour Completion Time begins at the time the Condition is entered and each "Once per 8 hours thereafter" interval begins upon performance of Required Action A.1. | ||
If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour or any subsequent 8 hour interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Tme clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with (continued) | If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour or any subsequent 8 hour interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Tme clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with (continued) | ||
CALLAWAY PLANT 1.3-1 2 Amendment No. 133 | CALLAWAY PLANT 1.3-1 2 Amendment No. 133 | ||
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Frequency 1.4 1.4 Frequency (continued) | Frequency 1.4 1.4 Frequency (continued) | ||
EXAMPLES The following examples illustrate the various ways that Frequencies are specified. Inthese examples, the Applicability of the LCO (LCO not shown) is MODES 1,2, and 3. | EXAMPLES The following examples illustrate the various ways that Frequencies are specified. Inthese examples, the Applicability of the LCO (LCO not shown) is MODES 1,2, and 3. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours, an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable. | ||
If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4. | If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4. | ||
(continued) | (continued) | ||
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SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY | ||
+ | + | ||
Verify flow is within limits. Once within | Verify flow is within limits. Once within 12 hours after 2 25% RTP AND 24 hours thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level | ||
< 25% RTP to 2 25% RTP, the Surveillance must be performed within | < 25% RTP to 2 25% RTP, the Surveillance must be performed within 12 hours. | ||
The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). | The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). | ||
This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2. 'Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to | This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2. 'Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to | ||
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Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued) | Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued) | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY NOTE Not required to be performed until | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY NOTE Not required to be performed until 12 hours after 2 25% RTP. | ||
Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is < 25% RTP between performances. | Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is < 25% RTP between performances. | ||
As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows | As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours after power reaches 2 25% RTP to perform the Surveillance. | ||
The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was | The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was | ||
< 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed | < 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours with power 2 25% RTP. | ||
Once the unit reaches 25% RTP, | Once the unit reaches 25% RTP, 12 hours would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply. | ||
CALLAWAY PLANT 1.4-4 Amendment No. 133 | CALLAWAY PLANT 1.4-4 Amendment No. 133 | ||
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Ifthe LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated. | Ifthe LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated. | ||
LCO 3.0.3 When an'LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour to place the unit, as applicable, In: | LCO 3.0.3 When an'LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour to place the unit, as applicable, In: | ||
: a. MODE 3 within | : a. MODE 3 within 7 hours; | ||
: b. MODE 4 within | : b. MODE 4 within 13 hours; and | ||
: c. MODE 5 within | : c. MODE 5 within 37 hours. | ||
Exceptions to this Specification are stated in the individual Specifications. | Exceptions to this Specification are stated in the individual Specifications. | ||
Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required. | Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required. | ||
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LCO 3.0.7 Test Exception LCO 3.1.8 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with a Test Exception LCO is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications. | LCO 3.0.7 Test Exception LCO 3.1.8 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with a Test Exception LCO is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications. | ||
LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and: | LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and: | ||
: a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within | : a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours: or | ||
: b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem-supported system and are able to perform their associated support function within | : b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem-supported system and are able to perform their associated support function within 12 hours. | ||
At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared not met. | At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared not met. | ||
CALLAWAY PLANT 3.0-3 Amendment 179 | CALLAWAY PLANT 3.0-3 Amendment 179 | ||
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basis, the above Frequency extension applies to each performance after the initial performance. | basis, the above Frequency extension applies to each performance after the initial performance. | ||
Exceptions to this Specification are stated in the individual Specifications. | Exceptions to this Specification are stated in the individual Specifications. | ||
SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to | SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours and the risk impact shall be managed. | ||
If the Surveillance Is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. | If the Surveillance Is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. | ||
When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. | When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. | ||
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SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-1 Amendment No. 202 | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-1 Amendment No. 202 | ||
Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within + I% Ak/k of predicted values. | Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within + I% Ak/k of predicted values. | ||
APPLICABILITY: MODES I and 2. | APPLICABILITY: MODES I and 2. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. Measured core reactivity A.1 Re-evaluate core design 7 days not within limit. and safety analysis, and determine that the reactor core is acceptable for continued operation. | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. Measured core reactivity A.1 Re-evaluate core design 7 days not within limit. and safety analysis, and determine that the reactor core is acceptable for continued operation. | ||
AND A.2 Establish appropriate 7 days operating restrictions and SRs. | AND A.2 Establish appropriate 7 days operating restrictions and SRs. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. | ||
CALLAWAY PLANT 3.1-2 Amendment No. 133 | CALLAWAY PLANT 3.1-2 Amendment No. 133 | ||
| Line 355: | Line 351: | ||
LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be that specified in Figure 3.1.3-1. | LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be that specified in Figure 3.1.3-1. | ||
APPLICABILITY: MODE 1 and MODE 2 with kff 2 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit. | APPLICABILITY: MODE 1 and MODE 2 with kff 2 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. MTC not within upper limit. A.1 Establish administrative | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. MTC not within upper limit. A.1 Establish administrative 24 hours withdrawal limits for control banks to maintain MTC within limit. | ||
B. Required Action and B.1 Be in MODE 2 with | B. Required Action and B.1 Be in MODE 2 with 6 hours associated Completion k,,, < 1.0. | ||
Time of Condition A not met. | Time of Condition A not met. | ||
C. MTC not within lower limit. C.1 Be in MODE 4. | C. MTC not within lower limit. C.1 Be in MODE 4. 12 hours CALLAWAY PLANT 3.1-4 Amendment No. 133 | ||
MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE I after each refueling SR 3.1.3.2 NOTES | MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE I after each refueling SR 3.1.3.2 NOTES | ||
| Line 385: | Line 381: | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One or more rod(s) A.1.1 Verify SDM to be within 1 hour inoperable. the limits provided in the COLR. | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One or more rod(s) A.1.1 Verify SDM to be within 1 hour inoperable. the limits provided in the COLR. | ||
OR A.1.2 Initiate boration to restore 1 hour SDM to within limit. | OR A.1.2 Initiate boration to restore 1 hour SDM to within limit. | ||
AND A.2 Be in MODE 3. | AND A.2 Be in MODE 3. 6 hours (continued) | ||
CALLAWAY PLANT 3.1-7 Amendment No. 133 | CALLAWAY PLANT 3.1-7 Amendment No. 133 | ||
| Line 393: | Line 389: | ||
OR B.2.1.1 Verify SDM to be within 1 hour the limits provided in the COLR. | OR B.2.1.1 Verify SDM to be within 1 hour the limits provided in the COLR. | ||
OR B.2.1.2 Initiate boration to 1 hour restore SDM to within limit. | OR B.2.1.2 Initiate boration to 1 hour restore SDM to within limit. | ||
AND B.2.2 Reduce THERMAL | AND B.2.2 Reduce THERMAL 2 hours POWER to | ||
* 75% RTP. | * 75% RTP. | ||
AND B.2.3 Verify SDM to be within Once per | AND B.2.3 Verify SDM to be within Once per 12 hours the limits provided in the COLR. | ||
AND B.2.4 Perform SR 3.2.1.1 and | AND B.2.4 Perform SR 3.2.1.1 and 72 hours SR 3.2.1.2. | ||
AND B.2.5 Perform SR 3.2.2.1. | AND B.2.5 Perform SR 3.2.2.1. 72 hours (continued) | ||
CALLAWAY PLANT 3.1-8 Amendment No. 133 | CALLAWAY PLANT 3.1-8 Amendment No. 133 | ||
Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION B. (continued) B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions. | Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION B. (continued) B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions. | ||
C. Required Action and C.1 Be in MODE 3. | C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition B not met. | ||
D. More than one rod not D.1.1 Verify SDM to be within 1 hour within alignment limit. the limits provided in the COLR. | D. More than one rod not D.1.1 Verify SDM to be within 1 hour within alignment limit. the limits provided in the COLR. | ||
OR D.1.2 Initiate boration to 1 hour restore required SDM to within limit. | OR D.1.2 Initiate boration to 1 hour restore required SDM to within limit. | ||
AND D.2 Be in MODE 3. | AND D.2 Be in MODE 3. 6 hours CALLAWAY PLANT 3.1-9 Amendment No. 133 | ||
Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. In accordance with the Surveillance Frequency Control Program SR 3.1.4.2 Verify rod freedom of movement (trippability) by In accordance moving each rod not fully inserted in the core with the | Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. In accordance with the Surveillance Frequency Control Program SR 3.1.4.2 Verify rod freedom of movement (trippability) by In accordance moving each rod not fully inserted in the core with the | ||
| Line 417: | Line 413: | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1.1 Verify SDM to be within 1 hour banks not within limits. the limits provided in the COLR. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1.1 Verify SDM to be within 1 hour banks not within limits. the limits provided in the COLR. | ||
OR A.1.2 Initiate boration to restore 1 hour SDM to within limit. | OR A.1.2 Initiate boration to restore 1 hour SDM to within limit. | ||
AND A.2 Restore shutdown banks | AND A.2 Restore shutdown banks 2 hours to within limits. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. | ||
CALLAWAY PLANT 3.1-11 Amendment No. 133 | CALLAWAY PLANT 3.1-11 Amendment No. 133 | ||
| Line 428: | Line 424: | ||
ACTIONS CONDITION REQUIRED ACTION TIME A. Control bank insertion A.1.1 Verify SDM to be within 1 hour limits not met. the limits provided in the COLR. | ACTIONS CONDITION REQUIRED ACTION TIME A. Control bank insertion A.1.1 Verify SDM to be within 1 hour limits not met. the limits provided in the COLR. | ||
OR A.1.2 Initiate boration to 1 hour restore SDM to within limit. | OR A.1.2 Initiate boration to 1 hour restore SDM to within limit. | ||
AND A.2 Restore control bank(s) | AND A.2 Restore control bank(s) 2 hours to within limits. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.1-13 Amendment No. 133 | CALLAWAY PLANT 3.1-13 Amendment No. 133 | ||
| Line 436: | Line 432: | ||
OR B.1.2 Initiate boration to restore 1 hour SDM to within limit. | OR B.1.2 Initiate boration to restore 1 hour SDM to within limit. | ||
AND B.2 Restore control bank 2 hour sequence and overlap to within limits. | AND B.2 Restore control bank 2 hour sequence and overlap to within limits. | ||
C. Required Action and C.1 Be in MODE 3. | C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time not met. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is within Within | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is within Within 4 hours the limits specified in the COLR. prior to achieving criticality SR 3.1.6.2 Verify each control bank insertion is within the limits In accordance specified in the COLR. with the Surveillance Frequency Control Program (Continued) | ||
CALLAWAY PLANT 3.1-14 Amendment No. 202 | CALLAWAY PLANT 3.1-14 Amendment No. 202 | ||
| Line 448: | Line 444: | ||
----------------------------- NOTE------------------------------- | ----------------------------- NOTE------------------------------- | ||
Separate Condition entry is allowed for each inoperable rod position indicator and each demand position indicator. | Separate Condition entry is allowed for each inoperable rod position indicator and each demand position indicator. | ||
COMPLETION CONDITION REQUIRED ACTION TIME TIME A. One DRPI per group A.1 Verify the position of the Once per | COMPLETION CONDITION REQUIRED ACTION TIME TIME A. One DRPI per group A.1 Verify the position of the Once per 8 hours inoperable for one or more rods with inoperable groups. position indicators indirectly by using core power distribution measurement information. | ||
OR A.2 Reduce THERMAL 8 hour POWER to | OR A.2 Reduce THERMAL 8 hour POWER to | ||
* 50% RTP. | * 50% RTP. | ||
| Line 458: | Line 454: | ||
more groups. | more groups. | ||
AND B.2 Monitor and record RCS Once per 1 hour Tavg. | AND B.2 Monitor and record RCS Once per 1 hour Tavg. | ||
AND B.3 Verify the position of the Once per | AND B.3 Verify the position of the Once per 8 hours rods with inoperable position indicators indirectly by using core power distribution' measurement information. | ||
AND B.4 Restore inoperable | AND B.4 Restore inoperable 24 hours position indicators to OPERABLE status such that a maximum of one DRPI per group is inoperable. | ||
C. One or more rods with C.1 Verify the position of the | C. One or more rods with C.1 Verify the position of the 4 hours inoperable DRPIs have rods with inoperable been moved in excess of 24 position indicators steps in one direction since indirectly by using core the last determination of the power distribution rod's position. measurement information. | ||
OR C.2 Reduce THERMAL | OR C.2 Reduce THERMAL 8 hours POWER to _ 50% RTP. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.1-17 Amendment No. 182 | CALLAWAY PLANT 3.1-17 Amendment No. 182 | ||
Rod Position Indication 3.1.7 ACTIONS (continued) | Rod Position Indication 3.1.7 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION D. One demand position D.1.1 Verify by administrative Once per | CONDITION REQUIRED ACTION COMPLETION D. One demand position D.1.1 Verify by administrative Once per 8 hours indicator per bank means all DRPls for the inoperable for one or more affected banks are banks. OPERABLE. | ||
AND D.1.2 Verify the most Once per | AND D.1.2 Verify the most Once per 8 hours withdrawn rod and the least withdrawn rod of the affected banks are | ||
* 12 steps apart. | * 12 steps apart. | ||
OR D.2 Reduce THERMAL | OR D.2 Reduce THERMAL 8 hours POWER to s 50% RTP. | ||
E. Required Action and E.1 Be in MODE 3. | E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time not met. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the group Once prior to demand position for the full indicated range of rod criticality after travel. each removal of the reactor vessel head. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the group Once prior to demand position for the full indicated range of rod criticality after travel. each removal of the reactor vessel head. | ||
CALLAWAY PLANT 3.1-18 Amendment No. 133 | CALLAWAY PLANT 3.1-18 Amendment No. 133 | ||
| Line 517: | Line 512: | ||
APPLICABILITY: MODE 1. | APPLICABILITY: MODE 1. | ||
ACTIONS CONDITION REQUIRED ACTION TIME A. F&(Z) not within limit. A.1 Reduce THERMAL 15 minutes after POWER 2 1% RTP for each Fc(Z) each 1% Fca(Z) exceeds determination limit. | ACTIONS CONDITION REQUIRED ACTION TIME A. F&(Z) not within limit. A.1 Reduce THERMAL 15 minutes after POWER 2 1% RTP for each Fc(Z) each 1% Fca(Z) exceeds determination limit. | ||
AND A.2 Reduce Power Range | AND A.2 Reduce Power Range 72 hours after each Neutron Flux - High trip Fc(Z) determination setpoints 2 1% for each 1% Fc(Z) exceeds limit. | ||
AND A.3 Reduce Overpower AT | AND A.3 Reduce Overpower AT 72 hours after each trip setpoints 2 1% for Fc(Z) determination each 1% Fa(Z) exceeds limit. | ||
AND A.4 Perform SR 3.2.1.1. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued) | AND A.4 Perform SR 3.2.1.1. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued) | ||
CALLAWAY PLANT 3.2-1 Amendment No. 133 | CALLAWAY PLANT 3.2-1 Amendment No. 133 | ||
Fa(Z) (Fo Methodology) 3.2.1 ACTIONS (continued) | Fa(Z) (Fo Methodology) 3.2.1 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME B. Fwa(Z) not within limits. B.1 Reduce AFD limits 2 1% | COMPLETION CONDITION REQUIRED ACTION TIME B. Fwa(Z) not within limits. B.1 Reduce AFD limits 2 1% 4 hours for each 1% Fc(Z) exceeds limit. | ||
C. Required Action and C.1 Be in MODE 2. | C. Required Action and C.1 Be in MODE 2. 6 hours associated Completion Time not met. | ||
CALLAWAY PLANT 3.2-2 Amendment No. 133 | CALLAWAY PLANT 3.2-2 Amendment No. 133 | ||
| Line 530: | Line 525: | ||
----------------------------------------------------------- NOT E ---------------------------------------------------------- | ----------------------------------------------------------- NOT E ---------------------------------------------------------- | ||
During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained. | During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained. | ||
SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify F8(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP Once within | SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify F8(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP Once within 24 hours after achieving equilibrium conditions after exceeding, by | ||
~ 10% RTP, the THERMAL POWER at which F8(Z) was last verified In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-3 Amendment No. 202 | ~ 10% RTP, the THERMAL POWER at which F8(Z) was last verified In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-3 Amendment No. 202 | ||
| Line 545: | Line 540: | ||
CALLAWAY PLANT 3.2-4 Amendment No. 182 | CALLAWAY PLANT 3.2-4 Amendment No. 182 | ||
Fa(Z) (Fa Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued) Once within | Fa(Z) (Fa Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued) Once within 24 hours after achieving equilibrium conditions after exceeding, by | ||
~ 10% RTP, the THERMAL POWER at which was last verified In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-5 Amendment 202 | ~ 10% RTP, the THERMAL POWER at which was last verified In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-5 Amendment 202 | ||
FNA2H 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FIH) | FNA2H 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FIH) | ||
LCO 3.2.2 F&H shall be within the limits specified in the COLR. | LCO 3.2.2 F&H shall be within the limits specified in the COLR. | ||
APPLICABILITY: MODE 1. | APPLICABILITY: MODE 1. | ||
ACTIONS CONDITION REQUIRED ACTION TIME A. NOTE E A.1.1 Restore F&H to within | ACTIONS CONDITION REQUIRED ACTION TIME A. NOTE E A.1.1 Restore F&H to within 4 hours Required Actions A.2 limit. | ||
and A.3 must be completed whenever Condition A is OR entered. | and A.3 must be completed whenever Condition A is OR entered. | ||
A.1.2.1 Reduce THERMAL | A.1.2.1 Reduce THERMAL 4 hours POWER to < 50% RTP. | ||
F&H not within limit. | F&H not within limit. | ||
AND A.1.2.2 Reduce Power Range | AND A.1.2.2 Reduce Power Range 72 hours Neutron Flux - High trip setpoints to s 55% RTP. | ||
AND A.2 Perform SR 3.2.2.1. | AND A.2 Perform SR 3.2.2.1. 24 hours AND (continued) | ||
CALLAWAY PLANT 3.2-6 Amendment No. 133 | CALLAWAY PLANT 3.2-6 Amendment No. 133 | ||
FNAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION TIME A. (continued) A.3 - NOTE THERMAL POWER does not have to be reduced to comply with this Required Action. | FNAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION TIME A. (continued) A.3 - NOTE THERMAL POWER does not have to be reduced to comply with this Required Action. | ||
Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND | Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours after THERMAL POWER reaching 2 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours associated Completion Time not met. | ||
CALLAWAY PLANT 3.2-7 Amendment No. 133 | CALLAWAY PLANT 3.2-7 Amendment No. 133 | ||
| Line 581: | Line 574: | ||
LCO 3.2.4 The QPTR shall be s 1.02. | LCO 3.2.4 The QPTR shall be s 1.02. | ||
APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP. | APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. QPTR not within limit. A.1 Reduce THERMAL | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. QPTR not within limit. A.1 Reduce THERMAL 2 hours after each POWER > 3% from RTP QPTR for each 1% of QPTR determination | ||
> 1.00. | > 1.00. | ||
AND A.2 Determine QPTR. Once per | AND A.2 Determine QPTR. Once per 12 hours AND A.3 Perform SR 3.2.1.1, 24 hours after SR 3.2.1.2 and achieving SR 3.2.2.1. equilibrium conditions from a THERMAL POWER reduction per Required Action A.1 AND Once per 7 days thereafter AND (continued) | ||
CALLAWAY PLANT 3.2-1 0 Amendment No. 133 | CALLAWAY PLANT 3.2-1 0 Amendment No. 133 | ||
| Line 595: | Line 588: | ||
QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. (continued) A.6 NOTE Perform Required Action A.6 only after Required Action A.5 is completed. | QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. (continued) A.6 NOTE Perform Required Action A.6 only after Required Action A.5 is completed. | ||
Perform SR 3.2.1.1, | Perform SR 3.2.1.1, 24 hours after SR 3.2.1.2 and achieving SR 3.2.2.1. equilibrium conditions not to exceed 48 hours after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and B.1 Reduce THERMAL 4 hours associated Completion POWER to s 50% RTP. | ||
Time not met. | Time not met. | ||
CALLAWAY PLANT 3.2-1 2 Amendment No. 133 | CALLAWAY PLANT 3.2-1 2 Amendment No. 133 | ||
| Line 603: | Line 596: | ||
: 2. SR 3.2.4.2 may be performed in lieu of this Surveillance. | : 2. SR 3.2.4.2 may be performed in lieu of this Surveillance. | ||
Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control Program SR 3.2.4.2 --------------------------------- NOTE ---------------------------- | Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control Program SR 3.2.4.2 --------------------------------- NOTE ---------------------------- | ||
Not required to be performed until | Not required to be performed until 12 hours after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER | ||
> 75% RTP. | > 75% RTP. | ||
Verify QPTR is within limit using power distribution In accordance measurement information. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-13 Amendment No. 202 | Verify QPTR is within limit using power distribution In accordance measurement information. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-13 Amendment No. 202 | ||
RTS Instrumentation 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1 -1 shall be OPERABLE. | RTS Instrumentation 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1 -1 shall be OPERABLE. | ||
APPLICABILITY: According to Table 3.3.1-1. | APPLICABILITY: According to Table 3.3.1-1. | ||
ACTIONS I.Erf%1 IMLJ I r-Separate Condition entry is allowed for each Function. | ACTIONS I.Erf%1 IMLJ I r-Separate Condition entry is allowed for each Function. | ||
CONDITION REQUIRED ACTION COMPLETION A. One or more Functions A.1 Enter the Condition Immediately with one or more required referenced in channels or trains Table 3.3.1-1 for the inoperable. channel(s) or train(s). | CONDITION REQUIRED ACTION COMPLETION A. One or more Functions A.1 Enter the Condition Immediately with one or more required referenced in channels or trains Table 3.3.1-1 for the inoperable. channel(s) or train(s). | ||
B. One Manual Reactor Trip B.1 Restore channel to | B. One Manual Reactor Trip B.1 Restore channel to 48 hours channel inoperable. OPERABLE status. | ||
OR B.2 Be in MODE 3. | OR B.2 Be in MODE 3. 54 hours (continued) | ||
CALLAWAY PLANT 3.3-1, Amendment No. 133 | CALLAWAY PLANT 3.3-1, Amendment No. 133 | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
REQUIRED ACTION COMPLETION TIME CONDITION C. One channel or train C.1 Restore channel or train | REQUIRED ACTION COMPLETION TIME CONDITION C. One channel or train C.1 Restore channel or train 48 hours Inoperable. to OPERABLE status. I OR C.2.1 Initiate action to fully 48 hours insert all rods. | ||
AND C.2.2 Place the Rod Control | AND C.2.2 Place the Rod Control 49 hours System in a condition incapable of rod withdrawal. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.3-2 Amendment No. 164 | CALLAWAY PLANT 3.3-2 Amendment No. 164 | ||
k RTS Instrumentation 3.3.1 ACTIONS (continued) | k RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION D. One Power Range Neutron -- NOTE Flux - High channel The inoperable channel may be inoperable. bypassed for up to | CONDITION REQUIRED ACTION COMPLETION D. One Power Range Neutron -- NOTE Flux - High channel The inoperable channel may be inoperable. bypassed for up to 12 hours for surveillance testing and setpoint adjustment of other channels. | ||
D.1.1 ------- NOTE Only required when the Power Range Neutron Flux input to QPTR is inoperable. | D.1.1 ------- NOTE Only required when the Power Range Neutron Flux input to QPTR is inoperable. | ||
Perform SR 3.2.4.2. | Perform SR 3.2.4.2. 12 hours from discovery of THERMAL POWER >75% | ||
RTP AND Once per | RTP AND Once per 12 hours thereafter AND D.1.2 Place channel in trip. 72 hours OR D.2 Be in MODE 3. 78 hours (continued) | ||
CALLAWAY PLANT 3.3-3 Amendment No. 165 | CALLAWAY PLANT 3.3-3 Amendment No. 165 | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION E. One channel inoperable. NOTE - --- | CONDITION REQUIRED ACTION COMPLETION E. One channel inoperable. NOTE - --- | ||
The inoperable channel may be bypassed for up to | The inoperable channel may be bypassed for up to 12 hours for I surveillance testing of other channels. | ||
E.1 Place channel in trip. | E.1 Place channel in trip. 72 hours I OR E.2 Be in MODE 3. 78 hours I F. One Intermediate Range F.1 Reduce THERMAL 24 hours Neutron Flux channel POWER to < P-6. | ||
inoperable. | inoperable. | ||
OR F.2 Increase THERMAL | OR F.2 Increase THERMAL 24 hours POWER to > P-10. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.3-4 Amendment No. 165 | CALLAWAY PLANT 3.3-4 Amendment No. 165 | ||
| Line 642: | Line 633: | ||
CONDITION REQUIREDACTION TIME G. Two Intermediate Range Gi NOTE Neutron Flux channels Limited boron inoperable. concentration changes associated with RCS inventory control or limited plant temperature changes are allowed. | CONDITION REQUIREDACTION TIME G. Two Intermediate Range Gi NOTE Neutron Flux channels Limited boron inoperable. concentration changes associated with RCS inventory control or limited plant temperature changes are allowed. | ||
Suspend operations Immediately involving positive reactivity additions. | Suspend operations Immediately involving positive reactivity additions. | ||
AND G.2 Reduce THERMAL | AND G.2 Reduce THERMAL 2 hours POWER to < P-6. | ||
H. Not used. | H. Not used. | ||
: 1. One Source Range 1.1 ---- NOTE-Neutron Flux channel Limited boron inoperable. concentration changes associated with RCS inventory control or limited plant temperature changes are allowed. | : 1. One Source Range 1.1 ---- NOTE-Neutron Flux channel Limited boron inoperable. concentration changes associated with RCS inventory control or limited plant temperature changes are allowed. | ||
| Line 652: | Line 643: | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION K. One Source Range K.A Restore channel to | CONDITION REQUIRED ACTION COMPLETION K. One Source Range K.A Restore channel to 48 hours Neutron Flux channel OPERABLE status. | ||
inoperable. | inoperable. | ||
OR K.2.1 Initiate action to fully | OR K.2.1 Initiate action to fully 48 hours insert all rods. | ||
AND K.2.2 Place the Rod Control | AND K.2.2 Place the Rod Control 49 hours System in a condition incapable of rod withdrawal. | ||
L. Not used. | L. Not used. | ||
M. One channel inoperable. NOTE The inoperable channel may be bypassed for up to | M. One channel inoperable. NOTE The inoperable channel may be bypassed for up to 12 hours for I surveillance testing of other channels. | ||
M.1 Place channel in trip. | M.1 Place channel in trip. 72 hours I OR M.2 Reduce THERMAL 78 hours I POWER to < P-7. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.3-6 Amendment No. 165 | CALLAWAY PLANT 3.3-6 Amendment No. 165 | ||
| Line 664: | Line 655: | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION TIME N. Not used. | CONDITION REQUIRED ACTION TIME N. Not used. | ||
: 0. One Low Fluid Oil Pressure NOTE Turbine Trip channel The inoperable channel may be inoperable. bypassed for up to | : 0. One Low Fluid Oil Pressure NOTE Turbine Trip channel The inoperable channel may be inoperable. bypassed for up to 12 hours for surveillance testing of other channels. | ||
0.1 Place channel in trip. | 0.1 Place channel in trip. 72 hours OR 0.2 Reduce THERMAL 76 hours POWER to < P-9. | ||
P. One or more Turbine Stop RI Place channel(s) in trip. | P. One or more Turbine Stop RI Place channel(s) in trip. 72 hours Valve Closure Turbine Trip channel(s) inoperable. OR P.2 Reduce THERMAL 76 hours POWER to < P-9. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.3-7 Amendment No. 165 | CALLAWAY PLANT 3.3-7 Amendment No. 165 | ||
| Line 673: | Line 664: | ||
CONDITION REQUIRED ACTION ACTIONCOMPLETION TIME Q One train inoperable. ----------------- NOTE ---------- | CONDITION REQUIRED ACTION ACTIONCOMPLETION TIME Q One train inoperable. ----------------- NOTE ---------- | ||
One train may be bypassed for up to | One train may be bypassed for up to | ||
. | .4 hours for surveillance testing provided the other train is OPERABLE. | ||
Q.1 Restore train to | Q.1 Restore train to 24 hours OPERABLE status.. | ||
OR Q.2 Be in MODE 3. | OR Q.2 Be in MODE 3. 30 hours R One RTB train inoperable. -------------- NOTE ---------- | ||
One train may be bypassed for up to | One train may be bypassed for up to 4 hours for surveillance testing provided the other train is OPERABLE. | ||
R.1 Restore train to | R.1 Restore train to 24 hours OPERABLE status. | ||
OR R.2 Be in MODE 3. | OR R.2 Be in MODE 3. 30 hours S. One or more required S.1 Verify interlock is in 1 hour channel(s) inoperable, required state for existing unit conditions. | ||
OR S.2 Be in MODE 3. | OR S.2 Be in MODE 3. 7 hours (continued) | ||
CALLAWAY PLANT 3.3-8 Amendment No. 174 | CALLAWAY PLANT 3.3-8 Amendment No. 174 | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME T. One or more required T.1 Verify interlock is in 1 hour channel(s) inoperable, required state for existing unit conditions. | CONDITION REQUIRED ACTION COMPLETION TIME T. One or more required T.1 Verify interlock is in 1 hour channel(s) inoperable, required state for existing unit conditions. | ||
OR T.2 Be in MODE 2. | OR T.2 Be in MODE 2. 7 hours U. One trip mechanism A.1 Restore inoperable trip 48 hours inoperable for one RTB. mechanism to OPERABLE status. | ||
OR U.2 Be in MODE 3. | OR U.2 Be in MODE 3. 54 hours (continued) | ||
CALLAWAY PLANT 3.3-9 Amendment No. 174 | CALLAWAY PLANT 3.3-9 Amendment No. 174 | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
CONDITION I REQUIRED ACTION T COMPLETION TIME V. One channel inoperable. - ------------------- NOTE ---------- | CONDITION I REQUIRED ACTION T COMPLETION TIME V. One channel inoperable. - ------------------- NOTE ---------- | ||
The inoperable channelmay be bypassed for up to | The inoperable channelmay be bypassed for up to 12 hours for surveillance testing of other channels. | ||
V.1 Place channel in trip. | V.1 Place channel in trip. 72 hours OR V.2.1 Be in MODE 2 with 78 hours keff < 1.0. | ||
AND V.2.2.1 Initiate action to fully | AND V.2.2.1 Initiate action to fully 78 hours insert all rods. | ||
AND V.2.2.2 Initiate action to place | AND V.2.2.2 Initiate action to place 78 hours the Rod Control System in a condition incapable of rod withdrawal. | ||
OR V.2.3 Initiate action to borate | OR V.2.3 Initiate action to borate 78 hours the RCS to greater than the all rods out (ARO) critical boron concentration. | ||
+ + | + + | ||
W Not used. | W Not used. | ||
| Line 701: | Line 692: | ||
RTS Instrumentation 3.3.1 ACTIONS (continued) | RTS Instrumentation 3.3.1 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME X One or more Containment X.1 Place channel(s) in trip. | COMPLETION CONDITION REQUIRED ACTION TIME X One or more Containment X.1 Place channel(s) in trip. 72 hours Pressure - Environmental Allowance Modifier OR channel(s) inoperable. | ||
X.2 Be in MODE 3. | X.2 Be in MODE 3. 78 hours Y. One channel inoperable ---- NOTE ---------- | ||
The inoperable channel may be bypassed for up to | The inoperable channel may be bypassed for up to 12 hours for surveillance testing of other channels. | ||
Y1 Place channel in trip. | Y1 Place channel in trip. 72 hours I | ||
Z Required Action and Z.1.1 Initiate action to fully Immediately associated Completion insert all rods. | Z Required Action and Z.1.1 Initiate action to fully Immediately associated Completion insert all rods. | ||
Time of Condition Y not met. AND OR Z.1.2 Initiate action to place Immediately the Rod Control System Two or more channels in a condition incapable inoperable, of rod withdrawal. | Time of Condition Y not met. AND OR Z.1.2 Initiate action to place Immediately the Rod Control System Two or more channels in a condition incapable inoperable, of rod withdrawal. | ||
| Line 714: | Line 705: | ||
Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function. | Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function. | ||
SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 --------------------------------- NOTE --------------------------- | SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 --------------------------------- NOTE --------------------------- | ||
Not required to be performed until | Not required to be performed until 24 hours after THERMAL POWER is ~ 15% RTP. | ||
Compare results of calorimetric heat balance In accordance calculation to power range channel output. Adjust with the power range channel output if calorimetric heat Surveillance balance calculation results exceed power range Frequency channel output by more than +2% RTP. Control Program SR 3.3.1.3 --------------------------------- NOTE -------.------------------- | Compare results of calorimetric heat balance In accordance calculation to power range channel output. Adjust with the power range channel output if calorimetric heat Surveillance balance calculation results exceed power range Frequency channel output by more than +2% RTP. Control Program SR 3.3.1.3 --------------------------------- NOTE -------.------------------- | ||
Not required to be performed until | Not required to be performed until 24 hours after THERMAL POWER is ~ 50% RTP. | ||
Compare results of the incore power distribution In accordance measurements to Nuclear Instrumentation System with the (NIS) AFD. Adjust NIS channel if absolute difference Surveillance is ~2%. Frequency Control Program (continued) | Compare results of the incore power distribution In accordance measurements to Nuclear Instrumentation System with the (NIS) AFD. Adjust NIS channel if absolute difference Surveillance is ~2%. Frequency Control Program (continued) | ||
CALLAWAY PLANT 3.3-12 Amendment No. 202 | CALLAWAY PLANT 3.3-12 Amendment No. 202 | ||
| Line 723: | Line 714: | ||
This Surveillance must be performed on the reactor trip bypass breaker for the local manual shunt trip only prior to placing the bypass breaker in service. | This Surveillance must be performed on the reactor trip bypass breaker for the local manual shunt trip only prior to placing the bypass breaker in service. | ||
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 --------------------------------- NOTE --------------------------- | Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 --------------------------------- NOTE --------------------------- | ||
Not required to be performed until | Not required to be performed until 72 hours after achieving equilibrium conditions with THERMAL POWER ~ 75 % RTP. | ||
Calibrate excore channels to agree with incore power In accordance distribution measurements. with the Surveillance Frequency Control Program (continued) | Calibrate excore channels to agree with incore power In accordance distribution measurements. with the Surveillance Frequency Control Program (continued) | ||
CALLAWAY PLANT 3.3-13 Amendment No. 202 | CALLAWAY PLANT 3.3-13 Amendment No. 202 | ||
| Line 729: | Line 720: | ||
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued) | RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued) | ||
SURVEILLANCE FREQUENCY SR 3.3.1.7 --------------------------------- NOTE --------------------------- | SURVEILLANCE FREQUENCY SR 3.3.1.7 --------------------------------- NOTE --------------------------- | ||
: 1. Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until | : 1. Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours after entry into MODE 3. | ||
: 2. Source range instrumentation shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions. | : 2. Source range instrumentation shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions. | ||
Perform COT. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-14 Amendment No. 202 | Perform COT. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-14 Amendment No. 202 | ||
| Line 737: | Line 728: | ||
This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions. | This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions. | ||
Perform COT. ------- NOTE ------- | Perform COT. ------- NOTE ------- | ||
Only required when not performed within the frequency specified in the Surveillance Frequency Control Program Prior to reactor startup | Only required when not performed within the frequency specified in the Surveillance Frequency Control Program Prior to reactor startup 12 hours after reducing power below P-10 for power and intermediate instrumentation Four hours after reducing power below P-6 for source range instrumentation CALLAWAY PLANT 3.3-15 Amendment No. 202 | ||
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.8 (continued) | RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.8 (continued) | ||
| Line 751: | Line 742: | ||
: 1. Neutron detectors are excluded from CHANNEL CALIBRATION. | : 1. Neutron detectors are excluded from CHANNEL CALIBRATION. | ||
: 2. This Surveillance shall include verification that the time constants are adjusted to the prescribed values. | : 2. This Surveillance shall include verification that the time constants are adjusted to the prescribed values. | ||
: 3. Power and intermediate range detector plateau voltage verification is not required to be performed until | : 3. Power and intermediate range detector plateau voltage verification is not required to be performed until 72 hours after achieving equilibrium conditions with THERMAL POWER 2 95% RTP. | ||
Perform CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Not used. | Perform CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Not used. | ||
SR 3.3.1.13 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 --------------------------------- NOTE --------------------------- | SR 3.3.1.13 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 --------------------------------- NOTE --------------------------- | ||
| Line 789: | Line 780: | ||
: 8. Pressurizer Pressure | : 8. Pressurizer Pressure | ||
: a. Low 1(9) 4 M .; | : a. Low 1(9) 4 M .; | ||
'l ;:, 1874 psig | 'l ;:, 1874 psig | ||
: b. High 1,2 4 E 1 1 :s: 2393 psig 1 r (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints. | : b. High 1,2 4 E 1 1 :s: 2393 psig 1 r (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints. | ||
| Line 896: | Line 886: | ||
Separate Condition entry is allowed for each Function. | Separate Condition entry is allowed for each Function. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 Enter the Condition Immediately one or more required referenced in channels or trains Table 3.3.2-1 for the inoperable. channel(s) or train(s). | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 Enter the Condition Immediately one or more required referenced in channels or trains Table 3.3.2-1 for the inoperable. channel(s) or train(s). | ||
B. One channel or train B.1 Restore channel or train | B. One channel or train B.1 Restore channel or train 48 hours inoperable. to OPERABLE status. | ||
OR B.2.1 Be in MODE 3. | OR B.2.1 Be in MODE 3. 54 hours 81:iD. | ||
B.2.2 Be in MODE 5. | B.2.2 Be in MODE 5. 84 hours (continued) | ||
CALLAWAY PLANT 3.3-27 Amendment No. 202 I | CALLAWAY PLANT 3.3-27 Amendment No. 202 I | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. One train inoperable. ------------------- NOTE ------------------ | COMPLETION CONDITION REQUIRED ACTION TIME C. One train inoperable. ------------------- NOTE ------------------ | ||
One train may be bypassed for up to | One train may be bypassed for up to 4 hours for surveillance testing provided the other train is OPERABLE. | ||
C.1 ------------ NOTE ---------- | C.1 ------------ NOTE ---------- | ||
Only required if Function 3.a.(2) is inoperable. | Only required if Function 3.a.(2) is inoperable. | ||
Place and maintain Immediately containment purge supply and exhaust valves in closed position. | Place and maintain Immediately containment purge supply and exhaust valves in closed position. | ||
AND C.2 Restore train to | AND C.2 Restore train to 24 hours OPERABLE status. | ||
OR C.3.1 Be in MODE 3. | OR C.3.1 Be in MODE 3. 30 hours AND C.3.2 Be in MODE 5. 60 hours l continued} | ||
CALLAWAY PLANT 3.3-28 Amendment No. 202 I | CALLAWAY PLANT 3.3-28 Amendment No. 202 I | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME D. One channel inoperable. ------------------- NOTE ------------------ | COMPLETION CONDITION REQUIRED ACTION TIME D. One channel inoperable. ------------------- NOTE ------------------ | ||
The inoperable channel may be bypassed for up to | The inoperable channel may be bypassed for up to 12 hours for surveillance testing of other channels. | ||
D.1 Place channel in trip. 72 hours OR D.2.1 Be in MODE 3. 78 hours AND D.2.2 Be in MODE 4. 84 hours E. One Containment Pressure ------------------- NOTE ------------------ | |||
D.1 Place channel in trip. | channel inoperable. One additional channel may be bypassed for up to 12 hours for surveillance testing. | ||
channel inoperable. One additional channel may be bypassed for up to | E.1 Place channel in bypass. 72 hours OR E.2.1 Be in MODE 3. 78 hours AND E.2.2 Be in MODE 4. 84 hours (contln ued ) | ||
E.1 Place channel in bypass. | |||
CALLAWAY PLANT 3.3-29 Amendment No. 202 I | CALLAWAY PLANT 3.3-29 Amendment No. 202 I | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME F. One channel or train F.1 Restore channel or train | COMPLETION CONDITION REQUIRED ACTION TIME F. One channel or train F.1 Restore channel or train 48 hours inoperable. to OPERABLE status. | ||
QB F.2.1 Be in MODE 3. | QB F.2.1 Be in MODE 3. 54 hours AND F.2.2 Be in MODE 4. 60 hours G One train inoperable. ------------------- NOTE ------------------ | ||
One train may be bypassed for up to | One train may be bypassed for up to 4 hours for surveillance testing provided the other train is OPERABLE. | ||
G.1 Restore train to 24 hours OPERABLE status. | |||
G.1 Restore train to | OR G.2.1 Be in MODE 3. 30 hours AND G.2.2 Be in MODE 4. 36 hours H. One or more trains ------------------- NOTE ------------------ | ||
OR G.2.1 Be in MODE 3. | inoperable. One train may be bypassed for up to 4 hours for surveillance testing provided the other train is OPERABLE. | ||
inoperable. One train may be bypassed for up to | |||
H.1 Declare associated Immediately Pressurizer PORV(s) inoperable. | H.1 Declare associated Immediately Pressurizer PORV(s) inoperable. | ||
(contlnueo) | (contlnueo) | ||
| Line 936: | Line 922: | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME I. One channel inoperable. ------------------ NOTE ------------------ | COMPLETION CONDITION REQUIRED ACTION TIME I. One channel inoperable. ------------------ NOTE ------------------ | ||
The inoperable channel may be bypassed for up to | The inoperable channel may be bypassed for up to 12 hours for surveillance testing of other channels. | ||
1.1 Place channel in trip. 72 hours OR 1.2 Be in MODE 3. 78 hours J. One channel inoperable. ------------------ NOTE ------------------ | |||
1.1 Place channel in trip. | The inoperable channel may be bypassed for up to 2 hours for surveillance testing of other channels. | ||
The inoperable channel may be bypassed for up to | J.1 Place channel in trip. 24 hours OR J.2 Be in MODE 3. 30 hours (ContinUed) | ||
J.1 Place channel in trip. | |||
CALLAWAY PLANT 3.3-31 Amendment No. 202 I | CALLAWAY PLANT 3.3-31 Amendment No. 202 I | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME K. One channel inoperable. ------------------- NOTE ------------------ | COMPLETION CONDITION REQUIRED ACTION TIME K. One channel inoperable. ------------------- NOTE ------------------ | ||
An inoperable channel may be bypassed for up to | An inoperable channel may be bypassed for up to 12 hours for surveillance testing of other channels. | ||
K.1 Restore channel to 72 hours OPERABLE status. | |||
K.1 Restore channel to | OR K.2.1 Be in MODE 3. 78 hours AND K.2.2 Be in MODE 5. 108 hours L. One or more required L.1 Verify interlock is in 1 hour channel{s) inoperable. required state for existing unit condition. | ||
OR K.2.1 Be in MODE 3. | OR L.2.1 Be in MODE 3. 7 hours AND L.2.2 Be in MODE 4. 13 hours (continued) | ||
OR L.2.1 Be in MODE 3. | |||
CALLAWAY PLANT 3.3-32 Amendment No. 202 I | CALLAWAY PLANT 3.3-32 Amendment No. 202 I | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME M. Two channels inoperable. M.1 Place channels in trip. | COMPLETION CONDITION REQUIRED ACTION TIME M. Two channels inoperable. M.1 Place channels in trip. 24 hours AND OR AFW actuation on Trip of all M.2 Be in MODE 3. 30 hours Main Feedwater Pumps maintained from one actuation train. | ||
N. One or more Containment N.1 Place channel(s) in trip. | N. One or more Containment N.1 Place channel(s) in trip. 72 hours Pressure - Environmental Allowance Modifier OR channel(s) inoperable. | ||
N.2.1 Be in MODE 3. | N.2.1 Be in MODE 3. 78 hours AND N.2.2 Be in MODE 4. 84 hours O. One channel inoperable. 0.1 Place channel in trip. 24 hours AND 0.2 Restore channel to During OPERABLE status. performance of the next required COT (continUed) | ||
CALLAWAY PLANT 3.3-33 Amendment No. 202 I | CALLAWAY PLANT 3.3-33 Amendment No. 202 I | ||
| Line 963: | Line 946: | ||
AND P.2 Declare associated Immediately steam generator blowdown and sample line isolation valve(s) inoperable. | AND P.2 Declare associated Immediately steam generator blowdown and sample line isolation valve(s) inoperable. | ||
Q One train inoperable. ------------------- NOTE ------------------ | Q One train inoperable. ------------------- NOTE ------------------ | ||
One train may be bypassed for up to | One train may be bypassed for up to 2 hours for surveillance testing provided the other train is OPERABLE. | ||
Q.1 Restore train to 24 hours OPERABLE status. | |||
Q.1 Restore train to | OR Q.2.1 Be in MODE 3. 30 hours AND Q.2.2 Be in MODE 4. 36 hours (continued) | ||
OR Q.2.1 Be in MODE 3. | |||
CALLAWAY PLANT 3.3-34 Amendment No. 202 I | CALLAWAY PLANT 3.3-34 Amendment No. 202 I | ||
ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ESFAS Instrumentation 3.3.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME R. One or both train(s) R.1 Restore train(s) to | COMPLETION CONDITION REQUIRED ACTION TIME R. One or both train(s) R.1 Restore train(s) to 48 hours inoperable. OPERABLE status. | ||
OR R.2.1 Be in MODE 3. | OR R.2.1 Be in MODE 3. 54 hours AND R.2.2 Be in MODE 4. 60 hours S. One train inoperable ------------------- NOTE ------------------ | ||
One train may be bypassed for up to | One train may be bypassed for up to 4 hours for surveillance testing provided the other train is OPERABLE. | ||
S.1 Restore train to 6 hours OPERABLE status. | |||
S.1 Restore train to | OR S.2.1 Be in MODE 3. 12 hours AND S.2.2 Be in MODE 4. 18 hours CALLAWAY PLANT 3.3-35 Amendment No. 202 I | ||
OR S.2.1 Be in MODE 3. | |||
ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS | ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS | ||
| Line 999: | Line 980: | ||
This Surveillance shall include verification that the time constants are adjusted to the prescribed values. | This Surveillance shall include verification that the time constants are adjusted to the prescribed values. | ||
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.10 --------------------------------- NOTE --------------------------- | Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.10 --------------------------------- NOTE --------------------------- | ||
Not required to be performed for the turbine driven AFW pump until | Not required to be performed for the turbine driven AFW pump until 24 hours after SG pressure is | ||
~ 900 psig. | ~ 900 psig. | ||
Verify ESF RESPONSE TIMES are within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.2.11 --------------------------------- NOTE --------------------------- | Verify ESF RESPONSE TIMES are within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.2.11 --------------------------------- NOTE --------------------------- | ||
| Line 1,011: | Line 992: | ||
K630, K740, and K741. | K630, K740, and K741. | ||
Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program Prior to entering MODE 4 when in MODE 5 or 6 | Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program Prior to entering MODE 4 when in MODE 5 or 6 | ||
> | > 24 hours, if not performed within the previous 92 days SR 3.3.2.14 --------------------------------- NOTE --------------------------- | ||
Only applicable to slave relays K620 and K750. | Only applicable to slave relays K620 and K750. | ||
Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program Prior to entering MODE 3 when in MODE 5 or 6 | Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program Prior to entering MODE 3 when in MODE 5 or 6 | ||
> | > 24 hours, if not performed within the previous 92 days CALLAWAY PLANT 3.3-39 Amendment No. 202 | ||
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 11) | ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 11) | ||
| Line 1,218: | Line 1,199: | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. One or more Functions with C.1 Restore all but one 7 days two or more required channel to OPERABLE channels inoperable. status. | COMPLETION CONDITION REQUIRED ACTION TIME C. One or more Functions with C.1 Restore all but one 7 days two or more required channel to OPERABLE channels inoperable. status. | ||
D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C not Table 3.3.3-1 for the met. channel. | D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C not Table 3.3.3-1 for the met. channel. | ||
E. As required by Required E.1 Be in MODE 3. | E. As required by Required E.1 Be in MODE 3. 6 hours Action D.1 and referenced in Table 3.3.3-1. AND E.2 Be in MODE 4. 12 hours F. As required by Required F.1 Initiate action in Immediately Action D.1 and referenced accordance with in Table 3.3.3-1. Specification 5.6.S. | ||
CALLAWAY PLANT 3.3-52 Amendment No. 202 , | CALLAWAY PLANT 3.3-52 Amendment No. 202 , | ||
| Line 1,262: | Line 1,243: | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.1 Restore required 30 days Functions inoperable. Function and required ASP controls to OPERABLE status. | COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.1 Restore required 30 days Functions inoperable. Function and required ASP controls to OPERABLE status. | ||
One or more required ASP controls inoperable. | One or more required ASP controls inoperable. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE4. 12 hours CALLAWAY PLANT 3.3-56 Amendment No. 202 I | ||
CALLAWAY PLANT 3.3-56 Amendment No. 202 I | |||
Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally energized. with the Surveillance Frequency Control Program SR 3.3.4.2 --------------------------------- NOTE --------------------------- | Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally energized. with the Surveillance Frequency Control Program SR 3.3.4.2 --------------------------------- NOTE --------------------------- | ||
| Line 1,271: | Line 1,250: | ||
: 1. Neutron detectors are excluded from CHANNEL CALIBRATION. | : 1. Neutron detectors are excluded from CHANNEL CALIBRATION. | ||
: 2. Reactor trip breaker and RCP breaker position indications are excluded from CHANNEL CALIBRATION. | : 2. Reactor trip breaker and RCP breaker position indications are excluded from CHANNEL CALIBRATION. | ||
Perform CHANNEL CALIBRATION for each required In accordance instrumentation channel. with the i Surveillance Frequency Control Program | Perform CHANNEL CALIBRATION for each required In accordance instrumentation channel. with the i Surveillance Frequency Control Program CALLAWAY PLANT 3.3-57 Amendment No. 202 | ||
CALLAWAY PLANT 3.3-57 Amendment No. 202 | |||
Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of 1) | Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of 1) | ||
| Line 1,297: | Line 1,274: | ||
Separate Condition entry is allowed for each Function. | Separate Condition entry is allowed for each Function. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 ------------ NOTE ---------- | COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 ------------ NOTE ---------- | ||
one channel per bus The inoperable channel inoperable. may be bypassed for up to | one channel per bus The inoperable channel inoperable. may be bypassed for up to 4 hours for surveillance testing of other channels. | ||
Place channel in trip. 6 hours B. One or more Functions with B.1 Declare associated load Immediately two or more channels per shedder and emergency bus inoperable. load sequencer (LSELS) inoperable. | |||
Place channel in trip. | |||
QB Required Action and associated Completion Time of Condition A not met. | QB Required Action and associated Completion Time of Condition A not met. | ||
CALLAWAY PLANT 3.3-59 Amendment No. 202 I | CALLAWAY PLANT 3.3-59 Amendment No. 202 I | ||
| Line 1,319: | Line 1,295: | ||
----------------------------------------------------------- NOT E ---------------------------------------------------------- | ----------------------------------------------------------- NOT E ---------------------------------------------------------- | ||
Separate Condition entry is allowed for each Function. | Separate Condition entry is allowed for each Function. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One radiation monitoring A.1 Restore the affected | COMPLETION CONDITION REQUIRED ACTION TIME A. One radiation monitoring A.1 Restore the affected 4 hours channel inoperable. channel to OPERABLE status. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.3-61 Amendment No. 202 I | CALLAWAY PLANT 3.3-61 Amendment No. 202 I | ||
| Line 1,385: | Line 1,361: | ||
AND C.1.2 Place one CREVS train 1 hour in CRVIS mode. | AND C.1.2 Place one CREVS train 1 hour in CRVIS mode. | ||
OR C.2 Place both trains in 1 hour CRVIS mode. | OR C.2 Place both trains in 1 hour CRVIS mode. | ||
D. Required Action and D.1 Be in MODE 3. | D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time for Conditions A, B, AND or C not met in MODE 1, 2, 3, or 4. D.2 Be in MODE 5. 36 hours E. Required Action and E.1 Suspend CORE Immediately associated Completion ALTERATIONS. | ||
Time for Conditions A, B, or C not met during CORE AND ALTERATIONS or during movement of irradiated fuel E.2 Suspend movement of Immediately assemblies. irradiated fuel assemblies. | Time for Conditions A, B, or C not met during CORE AND ALTERATIONS or during movement of irradiated fuel E.2 Suspend movement of Immediately assemblies. irradiated fuel assemblies. | ||
CALLAWAY PLANT 3.3-69 Amendment No. 202 I | CALLAWAY PLANT 3.3-69 Amendment No. 202 I | ||
| Line 1,479: | Line 1,455: | ||
: 3. During control bank movement in MODE 3; | : 3. During control bank movement in MODE 3; | ||
: 4. During shutdown bank movement in MODE 3. | : 4. During shutdown bank movement in MODE 3. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One train inoperable. A.1 Restore train to | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One train inoperable. A.1 Restore train to 72 hours OPERABLE status. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.3-79 Amendment No. 202 I | CALLAWAY PLANT 3.3-79 Amendment No. 202 I | ||
| Line 1,488: | Line 1,464: | ||
of Condition A not met. | of Condition A not met. | ||
Suspend operations Immediately involving positive reactivity additions. | Suspend operations Immediately involving positive reactivity additions. | ||
AND B.2 Perform SR 3.1.1.1. 1 hour AND Once per | AND B.2 Perform SR 3.1.1.1. 1 hour AND Once per 12 hours thereafter AND B.3.1 Close and secure 4 hours unborated water source isolation valves. | ||
AND B.3.2 Verify unborated water Once per 31 days source isolation valves are closed and secured. | AND B.3.2 Verify unborated water Once per 31 days source isolation valves are closed and secured. | ||
(continued) | (continued) | ||
| Line 1,494: | Line 1,470: | ||
BDMS 3.3.9 ACTIONS (continued) | BDMS 3.3.9 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME C. No RCS loop in operation. C.1 Close and secure | CONDITION REQUIRED ACTION COMPLETION TIME C. No RCS loop in operation. C.1 Close and secure 4 hours unborated water source isolation valves. | ||
AND C.2 Verify unborated water Once per 31 days source isolation valves are closed and secured. | AND C.2 Verify unborated water Once per 31 days source isolation valves are closed and secured. | ||
CALLAWAY PLANT 3.3-81 Amendment No. 202 I | CALLAWAY PLANT 3.3-81 Amendment No. 202 I | ||
| Line 1,501: | Line 1,477: | ||
Only required to be performed in MODE 5. | Only required to be performed in MODE 5. | ||
Verify BGV0178 is secured in the closed position. In accordance with the Surveillance Frequency Control Program SR 3.3.9.3 --------------------------------- NOT E --------------------------- | Verify BGV0178 is secured in the closed position. In accordance with the Surveillance Frequency Control Program SR 3.3.9.3 --------------------------------- NOT E --------------------------- | ||
Not required to be performed until | Not required to be performed until 4 hours after reducing power below P-6 interlock. | ||
Perform COT and verify nominal flux multiplication In accordance setpoint of 1.7. with the Surveillance Frequency Control Program SR 3.3.9.4 --------------------------------- NOTE --------------------------- | Perform COT and verify nominal flux multiplication In accordance setpoint of 1.7. with the Surveillance Frequency Control Program SR 3.3.9.4 --------------------------------- NOTE --------------------------- | ||
Neutron detectors are excluded from CHANNEL CALIBRATION. | Neutron detectors are excluded from CHANNEL CALIBRATION. | ||
| Line 1,515: | Line 1,491: | ||
APPLICABILITY: MODE 1. | APPLICABILITY: MODE 1. | ||
NOTE ------------- -------------------- | NOTE ------------- -------------------- | ||
Pressurizer pressure limit does not apply during: | Pressurizer pressure limit does not apply during: | ||
: a. THERMAL POWER ramp > 5% RTP per minute; or | : a. THERMAL POWER ramp > 5% RTP per minute; or | ||
: b. THERMAL POWER step > 10% RTP. | : b. THERMAL POWER step > 10% RTP. | ||
ACTIONS COMPLETIONTIME CONDITION REQUIRED ACTION TIME A. One or more RCS DNB A.1 Restore RCS DNB | ACTIONS COMPLETIONTIME CONDITION REQUIRED ACTION TIME A. One or more RCS DNB A.1 Restore RCS DNB 2 hours parameters not within limits, parameter(s) to within limit. | ||
B. Required Action and b B.1 Be in MODE 2. | B. Required Action and b B.1 Be in MODE 2. 6 hours associated Completion Time not met. | ||
CALLAWAY PLANT 3.4-1 Amendment No. 183 | CALLAWAY PLANT 3.4-1 Amendment No. 183 | ||
| Line 1,539: | Line 1,514: | ||
APPLICABILITY: At all times. | APPLICABILITY: At all times. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. -NOTE- A.1 Restore parameter(s) to 30 minutes Required Action A.2 shall within limits. | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. -NOTE- A.1 Restore parameter(s) to 30 minutes Required Action A.2 shall within limits. | ||
be completed whenever this Condition is entered. AND A.2 Determine RCS is | be completed whenever this Condition is entered. AND A.2 Determine RCS is 72 hours Requirements of LCO not acceptable for continued met in MODE 1, 2, 3, or 4. operation. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not AND met. | ||
B.2 Be in MODE 5 with RCS | B.2 Be in MODE 5 with RCS 36 hours pressure < 500 psig. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.4-4 Amendment No. 133 | CALLAWAY PLANT 3.4-4 Amendment No. 133 | ||
| Line 1,555: | Line 1,530: | ||
RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation. | RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation. | ||
APPLICABILITY: MODES 1 and 2. | APPLICABILITY: MODES 1 and 2. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Requirements of LCO not A.1 Be in MODE 3. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours met. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-6 Amendment No. 202 | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-6 Amendment No. 202 | ||
| Line 1,565: | Line 1,540: | ||
: b. Core outlet temperature is maintained at least 100 F below saturation temperature. | : b. Core outlet temperature is maintained at least 100 F below saturation temperature. | ||
APPLICABILITY: MODE 3. | APPLICABILITY: MODE 3. | ||
ACTIONS CONDITION REQUIRED ACTION TIME A. One required RCS loop A.1 Restore required RCS | ACTIONS CONDITION REQUIRED ACTION TIME A. One required RCS loop A.1 Restore required RCS 72 hours inoperable. loop to OPERABLE status. | ||
B. Required Action and B.1 Be in MODE 4. | B. Required Action and B.1 Be in MODE 4. 12 hours associated Completion Time of Condition A not met. | ||
(continued) | (continued) | ||
K> CALLAWAY PLANT 3.4-7 Amendment No. 149 | K> CALLAWAY PLANT 3.4-7 Amendment No. 149 | ||
| Line 1,593: | Line 1,568: | ||
AND A.2 --------- NOTE------ | AND A.2 --------- NOTE------ | ||
Only required if one RHR loop is OPERABLE. | Only required if one RHR loop is OPERABLE. | ||
Be in MODE 5. | Be in MODE 5. 24 hours (continued) | ||
CALLAWAY PLANT 3.4-1 0 Amendment No. 149 | CALLAWAY PLANT 3.4-1 0 Amendment No. 149 | ||
| Line 1,608: | Line 1,583: | ||
: a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and | : a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and | ||
: b. Core outlet temperature is maintained at least 10OF below saturation temperature. | : b. Core outlet temperature is maintained at least 10OF below saturation temperature. | ||
: 2. One required RHR loop may be inoperable for up to | : 2. One required RHR loop may be inoperable for up to 2 hours for surveillance testing provided that the other RHR loop is OPERABLE and in operation. | ||
: 3. No reactor coolant pump shall be started with any RCS cold leg temperature < 2750 F unless the secondary side water temperature of each SG is < 500 F above each of the RCS cold leg temperatures. | : 3. No reactor coolant pump shall be started with any RCS cold leg temperature < 2750 F unless the secondary side water temperature of each SG is < 500 F above each of the RCS cold leg temperatures. | ||
: 4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation. | : 4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation. | ||
| Line 1,630: | Line 1,605: | ||
: c. No draining operations to further reduce the RCS water volume are permitted. | : c. No draining operations to further reduce the RCS water volume are permitted. | ||
: 2. One RHR loop may be inoperable for | : 2. One RHR loop may be inoperable for | ||
* | * 2 hours for surveillance testing provided that the other RHR loop is OPERABLE and in operation. | ||
APPLICABILITY: MODE 5 with RCS loops not filled. | APPLICABILITY: MODE 5 with RCS loops not filled. | ||
ACTIONS CONDITION REQUIRED ACTION TIME A. One RHR loop inoperable. A.1 Initiate action to restore Immediately RHR loop to OPERABLE status. | ACTIONS CONDITION REQUIRED ACTION TIME A. One RHR loop inoperable. A.1 Initiate action to restore Immediately RHR loop to OPERABLE status. | ||
| Line 1,641: | Line 1,616: | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance are available to the required RHR pump that is not in with the operation. Surveillance Frequency Control Program CALLAWAY PLANT 3.4-16 Amendment No. 202 | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance are available to the required RHR pump that is not in with the operation. Surveillance Frequency Control Program CALLAWAY PLANT 3.4-16 Amendment No. 202 | ||
Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with: | Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with: | ||
: a. Pressurizer water level s 92%; and | : a. Pressurizer water level s 92%; and | ||
: b. Two groups of backup pressurizer heaters OPERABLE with the capacity of each group 2 150 kW. | : b. Two groups of backup pressurizer heaters OPERABLE with the capacity of each group 2 150 kW. | ||
APPLICABILITY: MODES 1, 2, and 3. | APPLICABILITY: MODES 1, 2, and 3. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Pressurizer water level not A.1 Be in MODE 3. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Pressurizer water level not A.1 Be in MODE 3. 6 hours within limit. | ||
AND A.2 Fully insert all rods. | AND A.2 Fully insert all rods. 6 hours AND A.3 Place Rod Control 6 hours System in a condition incapable of rod withdrawal. | ||
AND A.4 Be in MODE 4. | AND A.4 Be in MODE 4. 12 hours B. One required group of B.1 Restore required group 72 hours backup pressurizer heaters of backup pressurizer inoperable. heaters to OPERABLE status. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.4-1 7 Amendment No. 133 | CALLAWAY PLANT 3.4-1 7 Amendment No. 133 | ||
Pressurizer 3.4.9 ACTIONS (continued) | Pressurizer 3.4.9 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition B not AND met. | ||
C.2 Be in MODE 4. | C.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is s; 92%. In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of backup In accordance pressurizer heaters is :?: 150 kW. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-18 Amendment No. 202 | ||
Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings | Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings | ||
| Line 1,660: | Line 1,634: | ||
APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures> 275°F. | APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures> 275°F. | ||
------------------------------------------- NOTES ------------------------------------------- | ------------------------------------------- NOTES ------------------------------------------- | ||
The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for | The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours following entry into MODE 3 provided a preliminary cold setting was made prior to heatup. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 24 hours RCS cold leg Two or more pressurizer temperature::; 275°F. | ||
safety valves inoperable. | safety valves inoperable. | ||
CALLAWAY PLANT 3.4-19 Amendment No. 188 | CALLAWAY PLANT 3.4-19 Amendment No. 188 | ||
| Line 1,679: | Line 1,653: | ||
excessive seat leakage. | excessive seat leakage. | ||
AND B.2 Remove power from 1 hour associated block valve. | AND B.2 Remove power from 1 hour associated block valve. | ||
AND B.3 Restore PORV to | AND B.3 Restore PORV to 72 hours OPERABLE status. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.4-21 Amendment No. 188 | CALLAWAY PLANT 3.4-21 Amendment No. 188 | ||
| Line 1,687: | Line 1,661: | ||
inoperable. Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2. | inoperable. Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2. | ||
C.1 Place associated PORV 1 hour in manual control. | C.1 Place associated PORV 1 hour in manual control. | ||
AND C.2 Restore block valve to | AND C.2 Restore block valve to 72 hours OPERABLE status. | ||
D. Required Action and D.1 Be in MODE 3. | D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time of Condition A, B, or C not met. AND D.2 Be in MODE 4. 12 hours E. Two PORVs inoperable for E.1 Close associated block 1 hour reasons other than valves. | ||
excessive seat leakage. | excessive seat leakage. | ||
AND E.2 Remove power from 1 hour associated block valves. | AND E.2 Remove power from 1 hour associated block valves. | ||
AND E.3 Be in MODE 3. | AND E.3 Be in MODE 3. 6 hours AND E.4 Be in MODE 4. 12 hours (continued) | ||
CALLAWAY PLANT 3.4-22 Amendment No. 137 SEP 2 5 2000 | CALLAWAY PLANT 3.4-22 Amendment No. 137 SEP 2 5 2000 | ||
| Line 1,697: | Line 1,671: | ||
COMPLETION CONDITION REQUIRED ACTION TIME F. More than one block valve ------------------- NOTE ------------------ | COMPLETION CONDITION REQUIRED ACTION TIME F. More than one block valve ------------------- NOTE ------------------ | ||
inoperable. Required Action F.1 does not apply when block valve is inoperable solely as a result of complying with Required Action B.2 or E.2. | inoperable. Required Action F.1 does not apply when block valve is inoperable solely as a result of complying with Required Action B.2 or E.2. | ||
F.1 Restore one block valve 2 hours to OPERABLE status. | |||
F.1 Restore one block valve | G Required Action and 8.1 Be in MODE 3. 6 hours associated Completion Time of Condition F not AND met. | ||
G Required Action and 8.1 Be in MODE 3. | 8.2 Be in MODE 4. 12 hours CALLAWAY PLANT 3.4-23 Amendment No. 188 | ||
8.2 Be in MODE 4. | |||
Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------------------- NOT E -------------------------- | Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------------------- NOT E -------------------------- | ||
| Line 1,731: | Line 1,704: | ||
COMS 3.4.12 ACTIONS (continued) | COMS 3.4.12 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME D. Required Action and D.1 Increase all RCS cold | COMPLETION CONDITION REQUIRED ACTION TIME D. Required Action and D.1 Increase all RCS cold 12 hours associated Completion leg temperatures to Time of Condition C not > 275°F. | ||
met. | met. | ||
OR D.2 Depressurize affected | OR D.2 Depressurize affected 12 hours accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR. | ||
E. One required RCS relief E.1 Restore required RCS 7 days valve inoperable in relief valve to MODE4. OPERABLE status. | E. One required RCS relief E.1 Restore required RCS 7 days valve inoperable in relief valve to MODE4. OPERABLE status. | ||
F. One required RCS relief F.1 Restore required RCS | F. One required RCS relief F.1 Restore required RCS 24 hours valve inoperable in relief valve to MODE 5 or6. OPERABLE status. | ||
G Two required RCS relief G1 Depressurize RCS and | G Two required RCS relief G1 Depressurize RCS and 12 hours valves inoperable. establish RCS vent of | ||
~ 2.0 square inches. | ~ 2.0 square inches. | ||
OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met. | OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met. | ||
| Line 1,748: | Line 1,721: | ||
SURVEILLANCE FREQUENCY SR 3.4.12.6 Verify PORV block valve is open for each required In accordance PORV. with the Surveillance Frequency Control Program SR 3.4.12.7 Not used. | SURVEILLANCE FREQUENCY SR 3.4.12.6 Verify PORV block valve is open for each required In accordance PORV. with the Surveillance Frequency Control Program SR 3.4.12.7 Not used. | ||
SR 3.4.12.8 --------------------------------- NOTE --------------------------- | SR 3.4.12.8 --------------------------------- NOTE --------------------------- | ||
Not required to be performed until | Not required to be performed until 12 hours after decreasing any RCS cold leg temperature to ~ 275°F. | ||
Perform a COT on each required PORV, excluding In accordance actuation. with the Surveillance Frequency Control Program SR 3.4.12.9 Perform CHANNEL CALIBRATION for each required In accordance PORV actuation channel. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-29 Amendment No. 202 | Perform a COT on each required PORV, excluding In accordance actuation. with the Surveillance Frequency Control Program SR 3.4.12.9 Perform CHANNEL CALIBRATION for each required In accordance PORV actuation channel. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-29 Amendment No. 202 | ||
| Line 1,757: | Line 1,730: | ||
: d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG). | : d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG). | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. RCS operational A.1 Reduce LEAKAGE to | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. RCS operational A.1 Reduce LEAKAGE to 4 hours LEAKAGE not within limits within limits. | ||
'for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE. | 'for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not AND met. | ||
B.2 Be in MODE 5. | B.2 Be in MODE 5. 36 hours OR Pressure boundary LEAKAGE exists. | ||
OR Primary to secondary LEAKAGE not within limit. | OR Primary to secondary LEAKAGE not within limit. | ||
CALLAWAY PLANT 3.4-30 Amendment No. 168 | CALLAWAY PLANT 3.4-30 Amendment No. 168 | ||
RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 -------------------------- NOT ES ------------------------------ | RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 -------------------------- NOT ES ------------------------------ | ||
: 1. Not required to be performed until | : 1. Not required to be performed until 12 hours after establishment of steady state operation. | ||
: 2. Not applicable to primary to secondary LEAKAGE Verify RCS operational LEAKAGE is within limits by In accordance performance of RCS water inventory balance. with the Surveillance Frequency Control Program SR 3.4.13.2 -------------------------- NOTE ----------------------------- | : 2. Not applicable to primary to secondary LEAKAGE Verify RCS operational LEAKAGE is within limits by In accordance performance of RCS water inventory balance. with the Surveillance Frequency Control Program SR 3.4.13.2 -------------------------- NOTE ----------------------------- | ||
Not required to be performed until | Not required to be performed until 12 hours after establishment of steady state operation. | ||
Verify primary to secondary LEAKAGE is s 150 In accordance gallons per day through anyone SG. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-31 Amendment No. 202 | Verify primary to secondary LEAKAGE is s 150 In accordance gallons per day through anyone SG. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-31 Amendment No. 202 | ||
| Line 1,776: | Line 1,749: | ||
: 2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV. | : 2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV. | ||
CONDITION REQUIRED ACTION COMPLETION A. One or more flow paths A.1 - NOTE with leakage from one or Each valve used to satisfy more RCS PlVs not within Required Action A.1 must limit. have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary. | CONDITION REQUIRED ACTION COMPLETION A. One or more flow paths A.1 - NOTE with leakage from one or Each valve used to satisfy more RCS PlVs not within Required Action A.1 must limit. have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary. | ||
Isolate the high pressure | Isolate the high pressure 4 hours portion of the affected system from the low pressure portion by use of one deactivated remote manual or check valve. | ||
AND A.2 Restore RCS PIV to within | AND A.2 Restore RCS PIV to within 72 hours limits. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.4-32 Amendment No. 133 | CALLAWAY PLANT 3.4-32 Amendment No. 133 | ||
RCS PIV Leakage 3.4.14 ACTION (continued) | RCS PIV Leakage 3.4.14 ACTION (continued) | ||
CONDITION REQUIRED ACTION COMPLETION B. Required Action and B.1 Be in MODE 3. | CONDITION REQUIRED ACTION COMPLETION B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time for Condition A not AND met. | ||
B.2 Be in MODE 5. | B.2 Be in MODE 5. 36 hours C. RHR suction isolation valve C.1 Isolate the affected 4 hours interlock function penetration by use of inoperable. one deactivated remote manual valve. | ||
CALLAWAY PLANT 3.4-33 Amendment No. 133 | CALLAWAY PLANT 3.4-33 Amendment No. 133 | ||
| Line 1,795: | Line 1,768: | ||
CALLAWAY PLANT 3.4-34 Amendment No. 202 | CALLAWAY PLANT 3.4-34 Amendment No. 202 | ||
RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR3.4.14.1 (continued) Within | RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR3.4.14.1 (continued) Within 24 hours following check valve actuation due to flow through the valve SR 3.4.14.2 Verify RHR suction isolation valve interlock prevents In accordance the valves from being opened with a simulated or with the actual RCS pressure signal ~ 425 psig except when Surveillance the valves are open to satisfy LCO 3.4.12. Frequency Control Program CALLAWAY PLANT 3.4-35 Amendment 202 | ||
RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE: | RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE: | ||
| Line 1,802: | Line 1,775: | ||
: c. The containment cooler condensate monitoring system. I APPLICABILITY: MODES 1, 2, 3, and 4. | : c. The containment cooler condensate monitoring system. I APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. Required containment sump A.1 NOTE------ | ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. Required containment sump A.1 NOTE------ | ||
level and flow monitoring Not required until system inoperable. | level and flow monitoring Not required until system inoperable. 12 hours after establishment of steady state operation. | ||
Perform SR 3.4.13.1. Once per | Perform SR 3.4.13.1. Once per 24 hours AND A.2 Restore required 30 days containment sump level and flow monitoring system to OPERABLE status. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.4-36 Amendment No. 175 | CALLAWAY PLANT 3.4-36 Amendment No. 175 | ||
| Line 1,809: | Line 1,782: | ||
RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued) | RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued) | ||
CONDITION I | CONDITION I | ||
REQUIRED ACTION COMPLETION TIME TIME B. Required containment B.1.1 Analyze samples of the Once per | REQUIRED ACTION COMPLETION TIME TIME B. Required containment B.1.1 Analyze samples of the Once per 24 hours atmosphere particulate containment atmosphere. | ||
radioactivity monitor inoperable. OR B.1.2 NOTE------ ----- | radioactivity monitor inoperable. OR B.1.2 NOTE------ ----- | ||
Not required until | Not required until 12 hours after establishment of steady state operation. | ||
Perform SR 3.4.13.1. Once per | Perform SR 3.4.13.1. Once per 24 hours AND B.2.1 Restore required 30 days I containment atmosphere particulate radioactivity monitor to OPERABLE status. | ||
OR I. | OR I. | ||
B.2.2 Verify containment air 30 days cooler condensate monitoring system is OPERABLE. | B.2.2 Verify containment air 30 days cooler condensate monitoring system is OPERABLE. | ||
| Line 1,819: | Line 1,792: | ||
RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued) | RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued) | ||
COMPLETION TIME CONDITION REQUIRED ACTION TIME C. Required containment C.1 Perform SR 3.4.15.1. Once per | COMPLETION TIME CONDITION REQUIRED ACTION TIME C. Required containment C.1 Perform SR 3.4.15.1. Once per 8 hours cooler condensate monitoring system OR inoperable. | ||
C.2 NOTE------ | C.2 NOTE------ | ||
Not required until | Not required until 12 hours after establishment of steady state operation. | ||
Perform SR 3.4.13.1. Once per | Perform SR 3.4.13.1. Once per 24 hours I | ||
D. Required containment D.1 Restore required 30 days atmosphere particulate containment atmosphere radioactivity monitor particulate radioactivity inoperable. monitor to OPERABLE status. | D. Required containment D.1 Restore required 30 days atmosphere particulate containment atmosphere radioactivity monitor particulate radioactivity inoperable. monitor to OPERABLE status. | ||
AND OR Required containment cooler condensate D.2 Restore required 30 days monitoring system containment cooler inoperable, condensate monitoring system to OPERABLE status. | AND OR Required containment cooler condensate D.2 Restore required 30 days monitoring system containment cooler inoperable, condensate monitoring system to OPERABLE status. | ||
E. Required Action and E.1 Be in MODE 3. | E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours F.. All required monitoring F.1 Enter LCO 3.0.3. Immediately methods inoperable. | ||
CALLAWAY PLANT 3.4-38 Amendment No. 175 | CALLAWAY PLANT 3.4-38 Amendment No. 175 | ||
| Line 1,834: | Line 1,807: | ||
ACTIONS COM PLETION TIME CONDITION REQUIRED ACTION TIME A. DOSE EQUIVALENT ------------- NOTE ---------- | ACTIONS COM PLETION TIME CONDITION REQUIRED ACTION TIME A. DOSE EQUIVALENT ------------- NOTE ---------- | ||
1-131 not within limit. LCO 3.0.4.c is applicable. | 1-131 not within limit. LCO 3.0.4.c is applicable. | ||
A.1 Verify DOSE Once per | A.1 Verify DOSE Once per 4 hours EQUIVALENT 1-131 60 ipCi/gm. | ||
AND A.2 Restore DOSE 48 hours EQUIVALENT 1-1031 to within limit. | |||
60 ipCi/gm. | |||
AND A.2 Restore DOSE | |||
B. DOSE EQUIVALENT ------------- NOTE ---------- | B. DOSE EQUIVALENT ------------- NOTE ---------- | ||
XE-133 not within limit. LCO 3.0.4.c is applicable. | XE-133 not within limit. LCO 3.0.4.c is applicable. | ||
B.1 Restore DOSE | B.1 Restore DOSE 48 hours EQUIVALENT XE-133 to within limit. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.4-40 Amendment No. 178 | CALLAWAY PLANT 3.4-40 Amendment No. 178 | ||
RCS Specific Activity 3.4.16 ACTIONS (continued) | RCS Specific Activity 3.4.16 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition A orB AND not met. | ||
C.2 Be in MODE 5. | C.2 Be in MODE 5. 36 hours OR DOSE EQUIVALENT 1-131 | ||
> 60 J.!Ci/gm. | > 60 J.!Ci/gm. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 --------------------------------- N0 TE ---------------------------- | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 --------------------------------- N0 TE ---------------------------- | ||
| Line 1,855: | Line 1,826: | ||
SURVEILLANCE FREQUENCY SR 3.4.16.2 --------------------------------- NOTE --------------------------- | SURVEILLANCE FREQUENCY SR 3.4.16.2 --------------------------------- NOTE --------------------------- | ||
Only required to be performed in MODE 1. | Only required to be performed in MODE 1. | ||
Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance specific activity::; 1.0 ~Ci/gm. with the Surveillance Frequency Control Program Between 2 and | Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance specific activity::; 1.0 ~Ci/gm. with the Surveillance Frequency Control Program Between 2 and 6 hours after a THERMAL POWER change of ~ 15% RTP within a 1 hour period CALLAWAY PLANT 3.4-42 Amendment No. 202 | ||
SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained. | SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained. | ||
| Line 1,868: | Line 1,839: | ||
SG Tube Integrity 3.4.17 ACTIONS (continued) | SG Tube Integrity 3.4.17 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not AND met. | ||
B.2 Be in MODE 5. | B.2 Be in MODE 5. 36 hours SG tube integrity not maintained. | ||
CALLAWAY PLANT 3.4-44 Amendment No. 202 , | CALLAWAY PLANT 3.4-44 Amendment No. 202 , | ||
| Line 1,876: | Line 1,847: | ||
Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE. | Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE. | ||
APPLICABILITY: MODES 1 and 2, MODE 3 with RCS pressure > 1000 psig. | APPLICABILITY: MODES 1 and 2, MODE 3 with RCS pressure > 1000 psig. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One accumulator A.1 Restore boron | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One accumulator A.1 Restore boron 72 hours inoperable due to boron concentration to within concentration not within limits. | ||
limits. | limits. | ||
B. One accumulator B.1 Restore accumulator to | B. One accumulator B.1 Restore accumulator to 24 hours inoperable for reasons OPERABLE status. | ||
other than Condition A. | other than Condition A. | ||
C. Required Action and C.1 Be in MODE 3. | C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition A or B AND not met. | ||
C.2 Reduce RCS pressure to | C.2 Reduce RCS pressure to 12 hours s 1000 psig. | ||
D. Two or more accumulators D.1 Enter LCO 3.0.3. Immediately inoperable. | D. Two or more accumulators D.1 Enter LCO 3.0.3. Immediately inoperable. | ||
CALLAWAY PLANT 3.5-1 Amendment No. 133 | CALLAWAY PLANT 3.5-1 Amendment No. 133 | ||
| Line 1,893: | Line 1,864: | ||
SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance 2: 2300 ppm and:::; 2500 ppm. with the Surveillance Frequency Control Program AND | SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance 2: 2300 ppm and:::; 2500 ppm. with the Surveillance Frequency Control Program AND | ||
------- NOTE ------- | ------- NOTE ------- | ||
Only required to be performed for affected accumulators Once within | Only required to be performed for affected accumulators Once within 6 hours after each solution volume increase of 2: 70 gallons that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator In accordance isolation valve operator when RCS pressure is with the | ||
> 1000 psig. Surveillance Frequency Control Program CALLAWAY PLANT 3.5-3 Amendment No. 202 | > 1000 psig. Surveillance Frequency Control Program CALLAWAY PLANT 3.5-3 Amendment No. 202 | ||
ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE. | ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE. | ||
------------------------------------------- NOTES ------------------------------------------- | ------------------------------------------- NOTES ------------------------------------------- | ||
: 1. In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to | : 1. In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours to perform pressure isolation valve testing per SR 3.4.14.1. | ||
: 2. Operation in MODE 3 with ECCS pumps made incapable of injecting, pursuant to LCO 3.4.12, "Cold Overpressure Mitigation System," is allowed for up to | : 2. Operation in MODE 3 with ECCS pumps made incapable of injecting, pursuant to LCO 3.4.12, "Cold Overpressure Mitigation System," is allowed for up to 4 hours or until the temperature of all RCS cold legs exceeds 375°F, whichever comes first. | ||
APPLICABILITY: MODES 1, 2, and 3. | APPLICABILITY: MODES 1, 2, and 3. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more trains A.1 Restore train(s) to | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more trains A.1 Restore train(s) to 72 hours inoperable. OPERABLE status. | ||
AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available. | AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours CALLAWAY PLANT 3.5-4 Amendment No. 202 I | ||
ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position In accordance with power to the valve operator removed. with the Surveillance Number PO§jitioo Functioo Frequency BNHV8813 Open Safety Injection to RWST Control Program Isolation Valve EMHV8802A Closed SI Hot Legs 2 & 3 Isolation Valve EMHV8802B Closed SI Hot Legs 1 & 4 Isolation Valve EMHV8835 Open Safety Injection Cold Leg Isolation Valve EJHV8840 Closed RHRlSI Hot Leg Recirc Isolation Valve EJHV8809A Open RHR to Accum Inject Loops 1 & 2 Isolation Valve EJHV8809B Open RHR to Accum Inject Loops 3 & 4 Isolation Valve SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance automatic valve in the flow path, that is not locked, with the sealed, or otherwise secured in position, is in the Surveillance correct position. Frequency Control Program SR 3.5.2.3 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program (continued) | ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position In accordance with power to the valve operator removed. with the Surveillance Number PO§jitioo Functioo Frequency BNHV8813 Open Safety Injection to RWST Control Program Isolation Valve EMHV8802A Closed SI Hot Legs 2 & 3 Isolation Valve EMHV8802B Closed SI Hot Legs 1 & 4 Isolation Valve EMHV8835 Open Safety Injection Cold Leg Isolation Valve EJHV8840 Closed RHRlSI Hot Leg Recirc Isolation Valve EJHV8809A Open RHR to Accum Inject Loops 1 & 2 Isolation Valve EJHV8809B Open RHR to Accum Inject Loops 3 & 4 Isolation Valve SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance automatic valve in the flow path, that is not locked, with the sealed, or otherwise secured in position, is in the Surveillance correct position. Frequency Control Program SR 3.5.2.3 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program (continued) | ||
| Line 1,920: | Line 1,891: | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status. | COMPLETION CONDITION REQUIRED ACTION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status. | ||
B. Required ECCS Centrifugal B.1 Restore required ECCS 1 hour Charging Pump subsystem Centrifugal Charging inoperable. Pump subsystem to OPERABLE status. | B. Required ECCS Centrifugal B.1 Restore required ECCS 1 hour Charging Pump subsystem Centrifugal Charging inoperable. Pump subsystem to OPERABLE status. | ||
C. Required Action and C.1 Be in MODE 5. | C. Required Action and C.1 Be in MODE 5. 24 hours associated Completion Time of Condition B not met. | ||
CALLAWAY PLANT 3.5-7 Amendment No. 202 I | CALLAWAY PLANT 3.5-7 Amendment No. 202 I | ||
| Line 1,928: | Line 1,899: | ||
LCO 3.5.4 The RWST shall be OPERABLE. | LCO 3.5.4 The RWST shall be OPERABLE. | ||
APPLICABILITY: MODES 1,2, 3, and 4. | APPLICABILITY: MODES 1,2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RWST boron concentration A.1 Restore RWST to | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RWST boron concentration A.1 Restore RWST to 8 hours not within limits. OPERABLE status. | ||
OR RWST borated water temperature not within limits. | OR RWST borated water temperature not within limits. | ||
B. RWST inoperable for B.1 Restore RWST to 1 hour reasons other than OPERABLE status. | B. RWST inoperable for B.1 Restore RWST to 1 hour reasons other than OPERABLE status. | ||
Condition A. | Condition A. | ||
C. Required Action and C.1 Be in MODE 3. | C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.5-9 Amendment No. 202 I | ||
RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 --------------------------------- NOTE --------------------------- | RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 --------------------------------- NOTE --------------------------- | ||
| Line 1,940: | Line 1,911: | ||
Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow LCO 3.5.5 Reactor coolant pump (RCP) seal injection flow shall be within the limits of Figure 3.5.5-1. | Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow LCO 3.5.5 Reactor coolant pump (RCP) seal injection flow shall be within the limits of Figure 3.5.5-1. | ||
APPLICABILITY: MODES 1, 2, and 3. | APPLICABILITY: MODES 1, 2, and 3. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Seal injection flow not within A.1 Adjust manual seal | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Seal injection flow not within A.1 Adjust manual seal 4 hours limit. injection throttle valves such that the RCP seal injection flow is within the limits of Figure 3.5.5-1. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours CALLAWAY PLANT Amendment No. 202 I | ||
Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 --------------------------------- NOTE -------------------------- | Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 --------------------------------- NOTE -------------------------- | ||
Not required to be performed until | Not required to be performed until 4 hours after the Reactor Coolant System pressure stabilizes at | ||
~ 2215 psig and ~ 2255 psig. | ~ 2215 psig and ~ 2255 psig. | ||
Verify manual seal injection throttle valves are In accordance adjusted to give a flow within the limits of with the Figure 3.5.5-1. Surveillance Frequency Control Program CALLAWAY PLANT 3.5-12 Amendment No. 202 | Verify manual seal injection throttle valves are In accordance adjusted to give a flow within the limits of with the Figure 3.5.5-1. Surveillance Frequency Control Program CALLAWAY PLANT 3.5-12 Amendment No. 202 | ||
| Line 1,953: | Line 1,924: | ||
f,/) | f,/) | ||
@:. 190 | @:. 190 | ||
:::J 1/1 f 180-t~-~*~ | :::J 1/1 f 180-t~-~*~ | ||
0 f,/) | 0 f,/) | ||
~ 170 | ~ 170 | ||
;: 160 1~.,,***'t:*:4"' | ;: 160 1~.,,***'t:*:4"' | ||
.lil& | .lil& | ||
0 150 ~"~"f"''t.,--1'' | 0 150 ~"~"f"''t.,--1'' | ||
4'\1 | 4'\1 | ||
..c: | ..c: | ||
| Line 1,968: | Line 1,935: | ||
Delta P from Charging Header to RCS VS. Total Seal Injection Line Flow CALLAWAY PLANT Amendment No. 202 , | Delta P from Charging Header to RCS VS. Total Seal Injection Line Flow CALLAWAY PLANT Amendment No. 202 , | ||
*1 Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE. | *1 Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2,3, and 4. | APPLICABILITY: MODES 1, 2,3, and 4. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to 1 hour OPERABLE status. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to 1 hour OPERABLE status. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.6-1 Amendment No. 133 | ||
Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and leakage In accordance rate testing except for containment air lock testing, in with the accordance with the Containment Leakage Rate Containment Testing Program. Leakage Rate Testing Program SR 3.6.1.2 Verify containment structural integrity in accordance In accordance with the Containment Tendon Surveillance Program. with the Containment Tendon Surveillance Program CALLAWAY PLANT 3.6-2 Amendment No. 133 | Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and leakage In accordance rate testing except for containment air lock testing, in with the accordance with the Containment Leakage Rate Containment Testing Program. Leakage Rate Testing Program SR 3.6.1.2 Verify containment structural integrity in accordance In accordance with the Containment Tendon Surveillance Program. with the Containment Tendon Surveillance Program CALLAWAY PLANT 3.6-2 Amendment No. 133 | ||
Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE. | Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2,3, and 4. | APPLICABILITY: MODES 1, 2,3, and 4. | ||
| Line 1,989: | Line 1,954: | ||
CALLAWAY PLANT 3.6-3 Amendment No. 133 | CALLAWAY PLANT 3.6-3 Amendment No. 133 | ||
Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. (continued) A.2 Lock the OPERABLE | Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. (continued) A.2 Lock the OPERABLE 24 hours door closed in the affected air lock. | ||
AND A.3 NOTE Air lock doors in high radiation areas may be verified locked closed by administrative means. | AND A.3 NOTE Air lock doors in high radiation areas may be verified locked closed by administrative means. | ||
Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock. | Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock. | ||
| Line 1,995: | Line 1,960: | ||
: 2. Entry and exit of containment is permissible under the control of a dedicated individual. | : 2. Entry and exit of containment is permissible under the control of a dedicated individual. | ||
B.1 Verify an OPERABLE 1 hour door is closed in the affected air lock. | B.1 Verify an OPERABLE 1 hour door is closed in the affected air lock. | ||
AND B.2 Lock an OPERABLE | AND B.2 Lock an OPERABLE 24 hours door closed in the affected air lock. | ||
AND (continued) | AND (continued) | ||
CALLAWAY PLANT 3.6-4 Amendment No. 133 | CALLAWAY PLANT 3.6-4 Amendment No. 133 | ||
| Line 2,003: | Line 1,968: | ||
C. One or more containment C.1 Initiate action to evaluate Immediately air locks inoperable for overall containment reasons other than leakage rate per Condition A or B. LCO 3.6.1. | C. One or more containment C.1 Initiate action to evaluate Immediately air locks inoperable for overall containment reasons other than leakage rate per Condition A or B. LCO 3.6.1. | ||
AND C.2 Verify a door is closed in 1 hour the affected air lock. | AND C.2 Verify a door is closed in 1 hour the affected air lock. | ||
AND C.3 Restore air lock to | AND C.3 Restore air lock to 24 hours OPERABLE status. | ||
D. Required Action and D.1 Be in MODE 3. | D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.6-5 Amendment No. 133 | ||
Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY | Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY | ||
| Line 2,019: | Line 1,984: | ||
: 3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves. | : 3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves. | ||
: 4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria. | : 4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. NOTE A.1 Isolate the affected | ACTIONS CONDITION REQUIRED ACTION COMPLETION A. NOTE A.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths with use of at least one two containment isolation closed and de-activated valves. automatic valve, closed manual valve, blind flange, or check valve One or more penetration with flow through the flow paths with one valve secured. | ||
containment isolation valve inoperable except for AND containment purge valve leakage not within limit. | containment isolation valve inoperable except for AND containment purge valve leakage not within limit. | ||
___ ___ ___ ___ ___ ___ ____ ___ ___ ___ ___(continued) | ___ ___ ___ ___ ___ ___ ____ ___ ___ ___ ___(continued) | ||
CALLAWAY PLANT 3.6-7 Amendment No. 133 | CALLAWAY PLANT 3.6-7 Amendment No. 133 | ||
| Line 2,039: | Line 2,002: | ||
Containment Isolation Valves 3.6.3 ACTIONS (continued) | Containment Isolation Valves 3.6.3 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION TIME C. N NOTE C.1 Isolate the affected | CONDITION REQUIRED ACTION TIME C. N NOTE C.1 Isolate the affected 72 hours Only applicable to penetration flow path by penetration flow paths with use of at least one only one containment closed and de-activated isolation valves and a automatic valve, closed closed system. manual valve, or blind flange. | ||
One or more penetration AND flow paths with one containment isolation valve inoperable. C.2 NOTES | One or more penetration AND flow paths with one containment isolation valve inoperable. C.2 NOTES | ||
: 1. Isolation devices in high radiation areas may be verified by use of administrative means. | : 1. Isolation devices in high radiation areas may be verified by use of administrative means. | ||
| Line 2,048: | Line 2,011: | ||
Containment Isolation Valves 3.6.3 ACTIONS (continued) | Containment Isolation Valves 3.6.3 ACTIONS (continued) | ||
CONDITION C iCOMPLETION REQUIRED ACTION - TIME D. One or more penetration D.A Isolate the affected | CONDITION C iCOMPLETION REQUIRED ACTION - TIME D. One or more penetration D.A Isolate the affected 24 hours flow paths with one or penetration flow path by more containment purge use of at least one valves not within leakage closed and de-activated limits. automatic valve or blind flange. | ||
AND D.2 -_ NOTE S | AND D.2 -_ NOTE S | ||
: 1. Isolation devices in high radiation areas may be verified by use of administrative means. | : 1. Isolation devices in high radiation areas may be verified by use of administrative means. | ||
| Line 2,056: | Line 2,019: | ||
Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION TIME D. (continued) Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment AND D.3 Perform SR 3.6.3.6 or Once per 92 days SR 3.6.3.7 for the resilient seal purge valves closed to comply with Required Action D.1. | Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION TIME D. (continued) Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment AND D.3 Perform SR 3.6.3.6 or Once per 92 days SR 3.6.3.7 for the resilient seal purge valves closed to comply with Required Action D.1. | ||
E. Required Action and E.1 Be in MODE 3. | E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.6-12 Amendment No. 133 | ||
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment shutdown purge valve is In accordance sealed closed or closed and blind flange installed with the except for one purge valve in a penetration flow path Surveillance while in Condition D of this LCO. Frequency Control Program Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment SR 3.6.3.2 Verify each containment mini-purge valve is closed, In accordance except when the containment mini-purge valves are with the open for pressure control, ALARA or air quality Surveillance considerations for personnel entry, or for Frequency Surveillances that require the valves to be open. Control Program SR 3.6.3.3 --------------------------------- NOTE --------------------------- | Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment shutdown purge valve is In accordance sealed closed or closed and blind flange installed with the except for one purge valve in a penetration flow path Surveillance while in Condition D of this LCO. Frequency Control Program Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment SR 3.6.3.2 Verify each containment mini-purge valve is closed, In accordance except when the containment mini-purge valves are with the open for pressure control, ALARA or air quality Surveillance considerations for personnel entry, or for Frequency Surveillances that require the valves to be open. Control Program SR 3.6.3.3 --------------------------------- NOTE --------------------------- | ||
| Line 2,080: | Line 2,043: | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Containment pressure not A.1 Restore containment 1 hour within limits. pressure to within limits. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Containment pressure not A.1 Restore containment 1 hour within limits. pressure to within limits. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-16 Amendment No. 202 | ||
Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be ~ 120°F. | Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be ~ 120°F. | ||
APPLICABILITY: MODES 1. 2. 3. and 4. | APPLICABILITY: MODES 1. 2. 3. and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Containment average air A.1 Restore containment | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Containment average air A.1 Restore containment 8 hours temperature not within limit. average air temperature to within limit. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within In accordance limit. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-17 Amendment No. 202 | ||
Containment Spray and Cooling Systems 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray and Cooling Systems LCO 3.6.6 Two containment spray trains and two containment cooling trains shall be OPERABLE. | Containment Spray and Cooling Systems 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray and Cooling Systems LCO 3.6.6 Two containment spray trains and two containment cooling trains shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS CONDITION REQUIRED ACTION TIME A. One containment spray A.1 Restore containment | ACTIONS CONDITION REQUIRED ACTION TIME A. One containment spray A.1 Restore containment 72 hours train inoperable. spray train to OPERABLE status. AND 10 days from discovery of failure to meet the LCO B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not AND met. | ||
B.2 Be in MODE 5. | B.2 Be in MODE 5. 84 hours C. One containment cooling C.1 Restore containment 7 days train inoperable. cooling train to OPERABLE status. AND 10 days from discovery of failure to meet the LCO (continued) | ||
CALLAWAY PLANT 3.6-1 8 Amendment No. 133 | CALLAWAY PLANT 3.6-1 8 Amendment No. 133 | ||
Containment Spray and Cooling Systems 3.6.6 ACTIONS (continued) | Containment Spray and Cooling Systems 3.6.6 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME D. Required Action and D.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time of Condition C not AND met. | ||
D.2 Be in MODE 5. | D.2 Be in MODE 5. 36 hours E. Two containment spray E.1 Be in MODE 3. 6 hours trains inoperable. | ||
AND OR E.2 Be in MODE 5. | AND OR E.2 Be in MODE 5. 36 hours Two containment cooling trains inoperable. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance operated, and automatic valve in the flow path that is with the not locked, sealed, or otherwise secured in position is Surveillance in the correct position. Frequency Control Program SR 3.6.6.2 Operate each containment cooling train fan unit for In accordance 2: 15 minutes. with the Surveillance Frequency Control Program CALLAWAY PLANT Amendment No. 202 | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance operated, and automatic valve in the flow path that is with the not locked, sealed, or otherwise secured in position is Surveillance in the correct position. Frequency Control Program SR 3.6.6.2 Operate each containment cooling train fan unit for In accordance 2: 15 minutes. with the Surveillance Frequency Control Program CALLAWAY PLANT Amendment No. 202 | ||
| Line 2,104: | Line 2,067: | ||
Recirculation Fluid pH Control System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Recirculation Fluid pH Control (RFPC) System LCO 3.6.7 The RFPC System shall be OPERABLE. | Recirculation Fluid pH Control System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Recirculation Fluid pH Control (RFPC) System LCO 3.6.7 The RFPC System shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RFPC System inoperable. A.1 Restore RFPC System | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RFPC System inoperable. A.1 Restore RFPC System 72 hours to OPERABLE status. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify the integrity of the RFPC System. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-21 Amendment No. 202 | ||
Recirculation Fluid pH Control System 3.6.7 SURVEILLANCE REQUIREMENTS (continued) | Recirculation Fluid pH Control System 3.6.7 SURVEILLANCE REQUIREMENTS (continued) | ||
| Line 2,115: | Line 2,078: | ||
ACTIONS | ACTIONS | ||
-------------- - ---- NOTE Separate Condition entry is allowed for each MSSV. | -------------- - ---- NOTE Separate Condition entry is allowed for each MSSV. | ||
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam A.1 Reduce THERMAL | CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam A.1 Reduce THERMAL 4 hours generators with one MSSV POWER to < 85% RTR inoperable and the Moderator Temperature Coefficient (MTC) zero or negative at all power levels. | ||
B. One or more steam B.1 Reduce THERMAL | B. One or more steam B.1 Reduce THERMAL 4 hours generators with two or more POWER to less than or MSSV's inoperable, equal to the Maximum Allowable % RTP OR specified in Table 3.7.1-1 for the number of One or more steam OPERABLE'MSSVs. | ||
generators with one MSSV inoperable and the MTC AND positive at any power level. | generators with one MSSV inoperable and the MTC AND positive at any power level. | ||
(continued) | (continued) | ||
| Line 2,123: | Line 2,086: | ||
MSSVs 3.7.1 ACTIONS (continued) | MSSVs 3.7.1 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME B. (continued) B.2 N NOTE Only required in Mode 1. | COMPLETION CONDITION REQUIRED ACTION TIME B. (continued) B.2 N NOTE Only required in Mode 1. | ||
Reduce the Power | Reduce the Power 36 hours Range Neutron Flux - | ||
High Trip setpoints to less than or equal to the Maximum Allowable % | High Trip setpoints to less than or equal to the Maximum Allowable % | ||
RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs. | RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs. | ||
C. Required Action and C.1 Be in MODE 3. | C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time not met. AND OR C.2 Be in MODE 4. 12 hours One or more steam generators with 2 4 MSSVs inoperable. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 NOTE Only required to be performed in MODES 1 and 2. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 NOTE Only required to be performed in MODES 1 and 2. | ||
Verify each required MSSV lift setpoint perTable In accordance 3.7.1-2 in accordance with the Inservice Testing with the Inservice Program. Following testing, lift setting shall be within Testing Program | Verify each required MSSV lift setpoint perTable In accordance 3.7.1-2 in accordance with the Inservice Testing with the Inservice Program. Following testing, lift setting shall be within Testing Program | ||
| Line 2,136: | Line 2,099: | ||
STEAM GENERATOR 4 <85 3 *45 I 2 <27 CALLAWAY PLANT 3.7-3 Amendment No. 168 | STEAM GENERATOR 4 <85 3 *45 I 2 <27 CALLAWAY PLANT 3.7-3 Amendment No. 168 | ||
MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1) | MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1) | ||
Main Steam Safety Valve Lift Settings LIFT SETTING VALVE NUMBER (psig +3%/-l %) | Main Steam Safety Valve Lift Settings LIFT SETTING VALVE NUMBER (psig +3%/-l %) | ||
| Line 2,156: | Line 2,118: | ||
: b. MSLPDIV is closed and isolated by a closed manual valve, or | : b. MSLPDIV is closed and isolated by a closed manual valve, or | ||
: c. MSLPDIV is isolated by two closed manual valves. | : c. MSLPDIV is isolated by two closed manual valves. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One MSIV actuator train A.1 Restore MSIV actuator | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One MSIV actuator train A.1 Restore MSIV actuator 72 hours inoperable. | ||
train to OPERABLE status. | train to OPERABLE status. | ||
J L - -_ _- , _ . . . . . . , . . . - _ | J L - -_ _- , _ . . . . . . , . . . - _ | ||
(continuea] | (continuea] | ||
| Line 2,165: | Line 2,125: | ||
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 ACTIONS (continued) | MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME B. Two MSIV actuator trains B.1 Restore one MSIV | COMPLETION CONDITION REQUIRED ACTION TIME B. Two MSIV actuator trains B.1 Restore one MSIV 24 hours inoperable for different actuator train to MSIVs when the inoperable OPERABLE status. | ||
actuator trains are not in the same separation group. | actuator trains are not in the same separation group. | ||
C. Two MSIV actuator trains C.1 Restore one MSIV | C. Two MSIV actuator trains C.1 Restore one MSIV 4 hours inoperable when the actuator train to inoperable actuator trains OPERABLE status. | ||
are in the same separation group. | are in the same separation group. | ||
D. Two actuator trains for one D.1 Declare the affected Immediately MSIV inoperable. MSIV inoperable. | D. Two actuator trains for one D.1 Declare the affected Immediately MSIV inoperable. MSIV inoperable. | ||
E. Three or more MSIV E.1 Declare each affected Immediately actuator trains inoperable. MSIV inoperable. | E. Three or more MSIV E.1 Declare each affected Immediately actuator trains inoperable. MSIV inoperable. | ||
OR Required Action and associated Completion Time of Condition A, B, or C not met. | OR Required Action and associated Completion Time of Condition A, B, or C not met. | ||
F. One MSIV inoperable in F.1 Restore MSIV to | F. One MSIV inoperable in F.1 Restore MSIV to 8 hours MODE 1. OPERABLE status. | ||
G Required Action and G1 Be in MODE 2. | G Required Action and G1 Be in MODE 2. 6 hours associated Completion Time of Condition F not met. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.7-6 Amendment No. 197 | CALLAWAY PLANT 3.7-6 Amendment No. 197 | ||
| Line 2,179: | Line 2,139: | ||
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 ACTIONS (continued) | MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME H -------------- NOTE ------------ H.1 Close or isolate MSIVBV. 7 days Separate Condition entry is allowed for each main AND steam line. | COMPLETION CONDITION REQUIRED ACTION TIME H -------------- NOTE ------------ H.1 Close or isolate MSIVBV. 7 days Separate Condition entry is allowed for each main AND steam line. | ||
H.2 Verify MSIVBV is closed Once per 7 days One or more MSIVBVs or isolated. | H.2 Verify MSIVBV is closed Once per 7 days One or more MSIVBVs or isolated. | ||
inoperable. | inoperable. | ||
I. -------------- NOTE ------------ 1.1 Close or isolate 7 days Separate Condition entry is MSLPDIV. | I. -------------- NOTE ------------ 1.1 Close or isolate 7 days Separate Condition entry is MSLPDIV. | ||
allowed for each main steam line. AND | allowed for each main steam line. AND One or more MSLPDIVs 1.2 Verify MSLPDIV is Once per 7 days inoperable. closed or isolated. | ||
J. -------------- NOTE ------------ J.1 Close MSIV. 8 hours Separate Condition entry is allowed for each main AND steam line. | |||
One or more MSLPDIVs 1.2 Verify MSLPDIV is Once per 7 days inoperable. closed or isolated. | |||
J. -------------- NOTE ------------ J.1 Close MSIV. | |||
J.2 Verify MSIV is closed. Once per 7 days One or more MSIVs inoperable in MODE 2 or 3. | J.2 Verify MSIV is closed. Once per 7 days One or more MSIVs inoperable in MODE 2 or 3. | ||
K. Required Action and K.1 Be in MODE 3. | K. Required Action and K.1 Be in MODE 3. 6 hours associated Completion Time of Condition H, I, or J AND not met. | ||
K.2 Be in MODE 4. | K.2 Be in MODE 4. 12 hours CALLAWAY PLANT 3.7-7 Amendment No. 197 | ||
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.7.2.1 Verify isolation time of each MSIV is within limits. In accordance with the Inservice Testing Program SR 3.7.2.2 Verify each MSIV, each MSIVBV, and each MSLPDIV In accordance actuates to the isolation position on an actual or with the simulated actuation signal. Surveillance Frequency Control Program SR 3.7.2.3 Verify isolation time of each MSIVBV and MSLPDIV is In accordance with within limits. the Inservice Testing Program CALLAWAY PLANT 3.7-8 Amendment No. 202 | MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.7.2.1 Verify isolation time of each MSIV is within limits. In accordance with the Inservice Testing Program SR 3.7.2.2 Verify each MSIV, each MSIVBV, and each MSLPDIV In accordance actuates to the isolation position on an actual or with the simulated actuation signal. Surveillance Frequency Control Program SR 3.7.2.3 Verify isolation time of each MSIVBV and MSLPDIV is In accordance with within limits. the Inservice Testing Program CALLAWAY PLANT 3.7-8 Amendment No. 202 | ||
| Line 2,214: | Line 2,170: | ||
----------------------------------------------------------- NOTE ---------------------------------------------------------- | ----------------------------------------------------------- NOTE ---------------------------------------------------------- | ||
Separate Condition entry is allowed for each main feedwater line. | Separate Condition entry is allowed for each main feedwater line. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more MFIVs A.1 Close MFIV. | COMPLETION CONDITION REQUIRED ACTION TIME A. One or more MFIVs A.1 Close MFIV. 72 hours inoperable. | ||
AND A.2 Verify MFIV is closed. Once per 7 days B. One or more MFRVs B.1 Close or isolate MFRV. | AND A.2 Verify MFIV is closed. Once per 7 days B. One or more MFRVs B.1 Close or isolate MFRV. 72 hours inoperable. | ||
AND B.2 Verify MFRV is closed or Once per 7 days isolated. | AND B.2 Verify MFRV is closed or Once per 7 days isolated. | ||
C. One or more MFRVBVs C.1 Close or isolate | C. One or more MFRVBVs C.1 Close or isolate 72 hours inoperable. MFRVBV. | ||
AND C.2 Verify MFRVBV is closed Once per 7 days or isolated. | AND C.2 Verify MFRVBV is closed Once per 7 days or isolated. | ||
D. Two valves in the same 0.1 Isolate affected flow | D. Two valves in the same 0.1 Isolate affected flow 8 hours flow path inoperable. path. | ||
E. Required Action and E.1 Be in MODE 3. | E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours CALLAWAY PLANT 3.7-10 Amendment 198 | ||
MFIVs, MFRVs, and MFRVBVs 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 --------------------------------- NOT E --------------------------- | MFIVs, MFRVs, and MFRVBVs 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 --------------------------------- NOT E --------------------------- | ||
| Line 2,233: | Line 2,189: | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One required ASD line A.1 Restore required ASD 7 days inoperable for reasons line to OPERABLE other than excessive ASD status. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One required ASD line A.1 Restore required ASD 7 days inoperable for reasons line to OPERABLE other than excessive ASD status. | ||
seat leakage. | seat leakage. | ||
B. Two required ASD lines B.1 Restore all but one | B. Two required ASD lines B.1 Restore all but one 72 hours inoperable for reasons required ASD line to other than excessive ASD OPERABLE status. | ||
seat leakage. | seat leakage. | ||
C. Three or more required C.1 Restore all but two | C. Three or more required C.1 Restore all but two 24 hours ASD lines inoperable for required ASD lines to reasons other than OPERABLE status. | ||
excessive ASD seat leakage. | excessive ASD seat leakage. | ||
(continUed) | (continUed) | ||
| Line 2,243: | Line 2,199: | ||
COMPLETION CONDITION REQUIRED ACTION TIME D. One or more of the required D.1 Initiate action to close Immediately ASD(s) inoperable because the associated manual of excessive seat leakage. isolation valve(s). | COMPLETION CONDITION REQUIRED ACTION TIME D. One or more of the required D.1 Initiate action to close Immediately ASD(s) inoperable because the associated manual of excessive seat leakage. isolation valve(s). | ||
AND D.2 Restore ASD(s) to 30 days OPERABLE status. | AND D.2 Restore ASD(s) to 30 days OPERABLE status. | ||
E. Required Action and E.1 Be in MODE 3. | E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours CALLAWAY PLANT 3.7-13 Amendment No. 199 | ||
ASDs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 --------------------------------- NOTE --------------------------- | ASDs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 --------------------------------- NOTE --------------------------- | ||
| Line 2,255: | Line 2,211: | ||
LCO 3.0A.b is not applicable when entering MODE 1. | LCO 3.0A.b is not applicable when entering MODE 1. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One steam supply to A.1 Restore steam supply to 7 days turbine driven AFW pump OPERABLE status. | COMPLETION CONDITION REQUIRED ACTION TIME A. One steam supply to A.1 Restore steam supply to 7 days turbine driven AFW pump OPERABLE status. | ||
inoperable. AND 10 days from discovery of failure to meet the LCO B. One ESW supply to turbine B.1 Restore ESW supply to | inoperable. AND 10 days from discovery of failure to meet the LCO B. One ESW supply to turbine B.1 Restore ESW supply to 72 hours driven AFW pump OPERABLE status. | ||
inoperable. AND 10 days from discovery of failure to meet the LCO (continued) | inoperable. AND 10 days from discovery of failure to meet the LCO (continued) | ||
CALLAWAY PLANT 3.7-15 Amendment No. 198 I | CALLAWAY PLANT 3.7-15 Amendment No. 198 I | ||
AFW System 3.7.5 ACTIONS (continued) | AFW System 3.7.5 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. One AFW train inoperable C.1 Restore AFW train to | COMPLETION CONDITION REQUIRED ACTION TIME C. One AFW train inoperable C.1 Restore AFW train to 72 hours* | ||
for reasons other than OPERABLE status. | for reasons other than OPERABLE status. | ||
Condition A or B. AND 10 days from discovery of failure to meet the LCO D. Required Action and D.1 Be in MODE 3. | Condition A or B. AND 10 days from discovery of failure to meet the LCO D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time for Condition A, B AND or C not met. | ||
OR D.2 Be in MODE 4. | OR D.2 Be in MODE 4. 12 hours Two AFW trains inoperable. | ||
E. Three AFW trains E.1 ------------ No-rE ---------- | E. Three AFW trains E.1 ------------ No-rE ---------- | ||
inoperable. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status. | inoperable. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status. | ||
Initiate action to restore Immediately one AFW train to OPERABLE status. | Initiate action to restore Immediately one AFW train to OPERABLE status. | ||
*With the exception that the Completion Time associated with the Condition C entry on 2/3/04 for the turbine driven auxiliary feedwater pump has been extended on a one-time only basis to | *With the exception that the Completion Time associated with the Condition C entry on 2/3/04 for the turbine driven auxiliary feedwater pump has been extended on a one-time only basis to 144 hours. At the time a formal cause of the inoperability is determined, Condition D will be entered immediately. | ||
CALLAWAY PLANT 3.7-16 Amendment No. 198 I | CALLAWAY PLANT 3.7-16 Amendment No. 198 I | ||
| Line 2,274: | Line 2,229: | ||
Only required to be performed for the AFW flow control valves when the system is placed in automatic control or when THERMAL POWER is > 10% RTP. | Only required to be performed for the AFW flow control valves when the system is placed in automatic control or when THERMAL POWER is > 10% RTP. | ||
Verify each AFW manual, power operated, and In accordance automatic valve in each water flow path, and in both with the steam supply flow paths to the steam turbine driven Surveillance pump, that is not locked, sealed, or otherwise secured Frequency in position, is in the correct position. Control Program SR 3.7.5.2 --------------------------------- NOTE --------------------------- | Verify each AFW manual, power operated, and In accordance automatic valve in each water flow path, and in both with the steam supply flow paths to the steam turbine driven Surveillance pump, that is not locked, sealed, or otherwise secured Frequency in position, is in the correct position. Control Program SR 3.7.5.2 --------------------------------- NOTE --------------------------- | ||
Not required to be performed for the turbine driven AFW pump until | Not required to be performed for the turbine driven AFW pump until 24 hours after 2 900 psig in the steam generator. | ||
Verify the developed head of each AFW pump at the In accordance with flow test point is greater than or equal to the required the Inservice Test developed head. Program SR 3.7.5.3 Verify each AFW automatic valve that is not locked, In accordance sealed, or otherwise secured in position, actuates to with the the correct position on an actual or simulated Surveillance actuation signal. Frequency Control Program (continued) | Verify the developed head of each AFW pump at the In accordance with flow test point is greater than or equal to the required the Inservice Test developed head. Program SR 3.7.5.3 Verify each AFW automatic valve that is not locked, In accordance sealed, or otherwise secured in position, actuates to with the the correct position on an actual or simulated Surveillance actuation signal. Frequency Control Program (continued) | ||
CALLAWAY PLANT 3.7-17 Amendment No. 202 | CALLAWAY PLANT 3.7-17 Amendment No. 202 | ||
| Line 2,280: | Line 2,235: | ||
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued) | AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued) | ||
SURVEILLANCE FREQUENCY SR 3.7.5.4 --------------------------------- NOTE --------------------------- | SURVEILLANCE FREQUENCY SR 3.7.5.4 --------------------------------- NOTE --------------------------- | ||
Not required to be performed for the turbine driven AFW pump until | Not required to be performed for the turbine driven AFW pump until 24 hours after 2 900 psig in the steam generator. | ||
Verify each AFW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.5.5 Verify proper alignment of the required AFW flow Prior to entering paths by verifying flow from the condensate storage MODE 2 tank to each steam generator. whenever unit has been in MODE 5 or 6 for> 30 days CALLAWAY PLANT 3.7-18 Amendment No. 202 | Verify each AFW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.5.5 Verify proper alignment of the required AFW flow Prior to entering paths by verifying flow from the condensate storage MODE 2 tank to each steam generator. whenever unit has been in MODE 5 or 6 for> 30 days CALLAWAY PLANT 3.7-18 Amendment No. 202 | ||
| Line 2,286: | Line 2,241: | ||
LCO 3.7.6 The CST contained water volume shall be 2: 281,000 gal. | LCO 3.7.6 The CST contained water volume shall be 2: 281,000 gal. | ||
APPLICABILITY: MODES 1,2, and 3. | APPLICABILITY: MODES 1,2, and 3. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. CST contained water A.1 Verify by administrative | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. CST contained water A.1 Verify by administrative 4 hours volume not within limit. means OPERABILITY of backup water supply. AND AND Once per 12 hours thereafter A.2 Restore CST contained 7 days water volume to within limit. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours CALLAWAY PLANT 3.7-19 Amendment No. 198 I | ||
CST 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST contained water volume is In accordance | CST 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST contained water volume is In accordance | ||
| Line 2,297: | Line 2,252: | ||
Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4," | Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4," | ||
for residual heat removal loops made inoperable byCCW. | for residual heat removal loops made inoperable byCCW. | ||
Restore CCW train to 72 hours OPERABLE status. | |||
Restore CCW train to | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not AND met. | ||
B. Required Action and B.1 Be in MODE 3. | B.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.7-21 Amendment No. 198 I | ||
B.2 Be in MODE 5. | |||
CCWSystem 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 ----------------------------- NOTE ------------------------- | CCWSystem 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 ----------------------------- NOTE ------------------------- | ||
| Line 2,318: | Line 2,272: | ||
ESW 3.7.8 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One ESW train inoperable. A.1 (continued) --------NOTE------- | ESW 3.7.8 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One ESW train inoperable. A.1 (continued) --------NOTE------- | ||
A one-time Restore ESW train to Completion Time of OPERABLE status. 14 days is allowed to support planned replacement of ESW 'B' train piping prior to April 30, 2009. | A one-time Restore ESW train to Completion Time of OPERABLE status. 14 days is allowed to support planned replacement of ESW 'B' train piping prior to April 30, 2009. | ||
72 hours B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not met. AND B.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.7-24 Amendment 198 I | |||
ESW 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 --------------------------------- NOTE --------------------------- | ESW 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 --------------------------------- NOTE --------------------------- | ||
| Line 2,328: | Line 2,281: | ||
LCO 3.7.9 The UHS shall be OPERABLE. | LCO 3.7.9 The UHS shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One cooling tower train A.1 Restore cooling tower | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One cooling tower train A.1 Restore cooling tower 72 hours inoperable. train to OPERABLE status. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not AND met. | ||
OR B.2 Be in MODE 5. | OR B.2 Be in MODE 5. 36 hours UHS inoperable for reasons other than Condition A. | ||
CALLAWAY PLANT 3.7-26 Amendment No. 198 I | CALLAWAY PLANT 3.7-26 Amendment No. 198 I | ||
| Line 2,347: | Line 2,300: | ||
CREVS 3.7.10 ACTIONS (continued) | CREVS 3.7.10 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME B. One or more CREVS trains B.1 Initiate action to Immediately inoperable due to an implement mitigating inoperable CRE boundary or actions. | CONDITION REQUIRED ACTION COMPLETION TIME B. One or more CREVS trains B.1 Initiate action to Immediately inoperable due to an implement mitigating inoperable CRE boundary or actions. | ||
an inoperable CBE boundary in MODE 1,2,3, or4. AND B.2 Verify mitigating actions to | an inoperable CBE boundary in MODE 1,2,3, or4. AND B.2 Verify mitigating actions to 24 hours ensure CRE occupant radiological exposure will not exceed limits and CRE occupants are protected from chemical and smoke hazards. | ||
AND B.3 Restore the CRE 90 days boundary and CBE boundary to OPERABLE status. | AND B.3 Restore the CRE 90 days boundary and CBE boundary to OPERABLE status. | ||
C. Required Action and C.1 Be in MODE 3. | C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition A or B not met in MODE 1, 2, 3, or4. AND C.2 Be in MODE 5. 36 hours (continued) | ||
CALLAWAY PLANT 3.7-29 Amendment No. 198 I | CALLAWAY PLANT 3.7-29 Amendment No. 198 I | ||
| Line 2,371: | Line 2,324: | ||
APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies. | APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One CRACS train A.1 Restore CRACS train to 30 days inoperable. OPERABLE status. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One CRACS train A.1 Restore CRACS train to 30 days inoperable. OPERABLE status. | ||
B. Required Action and B.1 Be in MODE 3. | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time of Condition A not met AND in MODE 1,2,3, or4. | ||
B.2 Be in MODE 5. | B.2 Be in MODE 5. 36 hours (continued) | ||
CALLAWAY PLANT 3.7-32 Amendment No. 198 I | CALLAWAY PLANT 3.7-32 Amendment No. 198 I | ||
| Line 2,401: | Line 2,354: | ||
LCO 3.0.3 is not applicable to the FBVIS mode of operation. | LCO 3.0.3 is not applicable to the FBVIS mode of operation. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One EES train inoperable. A.1 Restore EES train to 7 days OPERABLE status. | COMPLETION CONDITION REQUIRED ACTION TIME A. One EES train inoperable. A.1 Restore EES train to 7 days OPERABLE status. | ||
B. Two EES trains inoperable B.1 Restore auxiliary building | B. Two EES trains inoperable B.1 Restore auxiliary building 24 hours due to inoperable auxiliary boundary to OPERABLE building boundary in status. | ||
MODE 1,2,3 or4. | MODE 1,2,3 or4. | ||
(continued) | (continued) | ||
| Line 2,407: | Line 2,360: | ||
Emergency Exhaust System 3.7.13 ACTIONS (continued) | Emergency Exhaust System 3.7.13 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition A or B not AND met in MODE 1, 2, 3, or 4. | ||
C.2 Be in MODE 5. | C.2 Be in MODE 5. 36 hours OR Two EES trains inoperable in MODE 1,2,3, or4 for reasons other than Condition B. | ||
D. Required Action and 0.1 Place OPERABLE EES Immediately associated Completion Time train in the FBVIS mode. | D. Required Action and 0.1 Place OPERABLE EES Immediately associated Completion Time train in the FBVIS mode. | ||
of Condition A not met during movement of irradiated fuel assemblies in the fuel building. | of Condition A not met during movement of irradiated fuel assemblies in the fuel building. | ||
| Line 2,448: | Line 2,401: | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify by administrative means the initial enrichment Prior to storing the andburnup of the fuel assembly is in accordance with fuel assembly in Figure 3.7.17-1 or Specification 4.3.1.1. Region 2 or 3 CALLAWAY PLANT 3.7-43 Amendment No. 198 I | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify by administrative means the initial enrichment Prior to storing the andburnup of the fuel assembly is in accordance with fuel assembly in Figure 3.7.17-1 or Specification 4.3.1.1. Region 2 or 3 CALLAWAY PLANT 3.7-43 Amendment No. 198 I | ||
Spent Fuel Assembly Storage 3.7.17 55000 | Spent Fuel Assembly Storage 3.7.17 55000 50000 | ||
50000 | |||
/ | / | ||
::J ACe ~EPTAB _E BUR NUP D )MAIN I FOR REGIO~ 2 AN D 3 S ORAGE | ::J ACe ~EPTAB _E BUR NUP D )MAIN I FOR REGIO~ 2 AN D 3 S ORAGE | ||
~ | ~ | ||
45000 c,"V | 45000 c,"V | ||
| Line 2,476: | Line 2,425: | ||
~ | ~ | ||
/ | / | ||
~o<<:- V | ~o<<:- V I | ||
I | |||
..J 25000 | ..J 25000 | ||
/ <)0 | / <)0 | ||
~~ | ~~ | ||
| Line 2,491: | Line 2,436: | ||
U - | U - | ||
20000 v h ~/ | 20000 v h ~/ | ||
..J CD | |||
..J | |||
CD | |||
~ | ~ | ||
w 15000 (J) | w 15000 (J) | ||
| Line 2,502: | Line 2,444: | ||
..J 10000 w | ..J 10000 w | ||
::J u | ::J u | ||
5000 | 5000 V UNAC CEPTAE LE aUF NUP 0 OMAIN FOR ~EGION 2 OR 3 STO ~AGE o I I I I I I I I I I I I 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 FUEL ASSEMBLY INITIAL ENRICHMENT (w/o U-235) | ||
V UNAC CEPTAE LE aUF NUP 0 OMAIN FOR ~EGION 2 OR 3 STO ~AGE | |||
o I I I I I I I I I I I I 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 FUEL ASSEMBLY INITIAL ENRICHMENT (w/o U-235) | |||
Figure 3.7.17-1 (page 1 of 1) | Figure 3.7.17-1 (page 1 of 1) | ||
MINIMUM REQUIRED FUEL ASSEMBLY BURNUP AS A FUNCTION OF INITIAL ENRICHMENT TO PERMIT STORAGE IN REGIONS 2 AND 3 CALLAWAY PLANT 3.7-44 Amendment No. 198 I | MINIMUM REQUIRED FUEL ASSEMBLY BURNUP AS A FUNCTION OF INITIAL ENRICHMENT TO PERMIT STORAGE IN REGIONS 2 AND 3 CALLAWAY PLANT 3.7-44 Amendment No. 198 I | ||
| Line 2,512: | Line 2,450: | ||
Secondary Specific Activity 3.7.18 3.7 PLANT SYSTEMS 3.7.18 Secondary Specific Activity LCO 3.7.18 The specific activity of the secondary coolant shall be 5 0.10 IlCi/gm DOSE EQUIVALENT 1-131. | Secondary Specific Activity 3.7.18 3.7 PLANT SYSTEMS 3.7.18 Secondary Specific Activity LCO 3.7.18 The specific activity of the secondary coolant shall be 5 0.10 IlCi/gm DOSE EQUIVALENT 1-131. | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Specific activity not within A.1 Be in MODE 3. | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours limit. | ||
AND A.2 Be in MODE 5. | AND A.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.18.1 Verify the specific activity of the secondary coolant is In accordance 50.10 IlCilgm DOSE EQUIVALENT 1-131. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-45 Amendment No. 202 | ||
SSIVs 3.7.19 3.7 PLANT SYSTEMS 3.7.19 Secondary System Isolation Valves (SSIVs) | SSIVs 3.7.19 3.7 PLANT SYSTEMS 3.7.19 Secondary System Isolation Valves (SSIVs) | ||
| Line 2,533: | Line 2,471: | ||
SSIVs 3.7.19 ACTIONS (continued) | SSIVs 3.7.19 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Be in MODE 3. 6 hours Associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 Verify the isolation time of each automatic SSIV is In accordance with within limits. the Inservice Testing Program SR 3.7.19.2 Verify each automatic SSIV in the flow path actuates In accordance to the isolation position on an actual or simulated with the actuation signal. Surveillance Frequency Control Program CALLAWAY PLANT 3.7-47 Amendment No. 202 | ||
AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE: | AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE: | ||
| Line 2,544: | Line 2,482: | ||
LCO 3.0.4.b is not applicable to DGs. | LCO 3.0.4.b is not applicable to DGs. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour inoperable. OPERABLE offsite circuit. | COMPLETION CONDITION REQUIRED ACTION TIME A. One offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour inoperable. OPERABLE offsite circuit. | ||
Once per | Once per 8 hours thereafter AND A.2 ------------ NOTE ---------- | ||
In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. | In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.8-1 Amendment No. 199 | CALLAWAY PLANT 3.8-1 Amendment No. 199 | ||
AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One offsite circuit Declare required | AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One offsite circuit Declare required 24 hours from inoperable. feature(s) with no offsite discovery of no (continued) power available offsite power to one inoperable when its train concurrent redundant required with inoperability of feature(s) is inoperable. redundant required feature(s) | ||
AND A.3 Restore offsite circuit to | AND A.3 Restore offsite circuit to 72 hours OPERABLE status. | ||
AND 6 days from discovery of failure to meet LCO B. One DG inoperable. B.1 Perform SR 3.8.1.1 for 1 hour the offsite circuit(s). | AND 6 days from discovery of failure to meet LCO B. One DG inoperable. B.1 Perform SR 3.8.1.1 for 1 hour the offsite circuit(s). | ||
AND Once per | AND Once per 8 hours thereafter AND B.2 NOTE - | ||
In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. | In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. | ||
(continued) | (continued) | ||
CALLAWAY PLANT 3.8-2 Amendment No. 133 | CALLAWAY PLANT 3.8-2 Amendment No. 133 | ||
AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME B. One DG inoperable. Declare required | AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME B. One DG inoperable. Declare required 4 hours from (continued) feature(s) supported by discovery of the inoperable DG Condition B inoperable when its concurrent with required redundant inoperability of feature(s) is inoperable. redundant required feature(s) | ||
AND B.3.1 Determine OPERABLE | AND B.3.1 Determine OPERABLE 24 hours DG is not inoperable due to common cause failure. | ||
OR B.3.2 ------------ NOTE ---------- | OR B.3.2 ------------ NOTE ---------- | ||
The required ACTION of B.3.2 is satisfied by the automatic start and sequence loading of the diesel generator. | The required ACTION of B.3.2 is satisfied by the automatic start and sequence loading of the diesel generator. | ||
Perform SR 3.8.1.2 for 24 hours OPERABLE DG. | |||
Perform SR 3.8.1.2 for | |||
AND (continued) | AND (continued) | ||
CALLAWAY PLANT 3.8-3 Amendment 186 | CALLAWAY PLANT 3.8-3 Amendment 186 | ||
| Line 2,568: | Line 2,505: | ||
AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME B. One DG inoperable. B.4 Restore DG to ---------NOTE-------- | AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME B. One DG inoperable. B.4 Restore DG to ---------NOTE-------- | ||
(continued) OPERABLE status. A one-time Completion Time of 14 days is allowed to support planned replacement of ESW 'B' train piping prior to April 30, 2009. | (continued) OPERABLE status. A one-time Completion Time of 14 days is allowed to support planned replacement of ESW 'B' train piping prior to April 30, 2009. | ||
72 hours AND 6 days from discovery of failure to meet LCO C. Two offsite circuits C.1 ------------ NO-rE ---------- | |||
inoperable. In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. | inoperable. In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. | ||
Declare required 12 hours from feature(s) inoperable discovery of when its redundant Condition C required feature(s) is concurrent with inoperable. inoperability of redundant required features AND (continued) | |||
Declare required | |||
CALLAWAY PLANT 3.8-4 Amendment 199 | CALLAWAY PLANT 3.8-4 Amendment 199 | ||
AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME C. Two offsite circuits C.2 Restore one offsite circuit | AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME C. Two offsite circuits C.2 Restore one offsite circuit 24 hours I to OPERABLE status. | ||
inoperable. | inoperable. | ||
I (continued) | I (continued) | ||
| Line 2,582: | Line 2,517: | ||
, Required Actions of LCO 3.8.9, AND I "Distribution Systems - Operating," | , Required Actions of LCO 3.8.9, AND I "Distribution Systems - Operating," | ||
when Condition D is entered with no One DG inoperable. I AC power source to any train. | when Condition D is entered with no One DG inoperable. I AC power source to any train. | ||
! D.1 Restore offsite circuit to 12 hours I OPERABLE status. | |||
! D.1 Restore offsite circuit to | OR D.2 Restore DG to 12 hours OPERABLE status. | ||
OR D.2 Restore DG to | E. Two D~s inoperable. E.1 Restore one DG to 2 hours I OPERABLE status. | ||
E. Two D~s inoperable. E.1 Restore one DG to | |||
F. One required LSELS F.1 Declare the affected DG Immediately inoperable. and offsite circuit inoperable. | F. One required LSELS F.1 Declare the affected DG Immediately inoperable. and offsite circuit inoperable. | ||
AND Restore required LSELS | AND Restore required LSELS 12 hours I F.2 to OPERABLE status. | ||
I (Continued) | I (Continued) | ||
CALLAWAY PLANT 3.8-5 Amendment 186 I | CALLAWAY PLANT 3.8-5 Amendment 186 I | ||
AC Sources - Operating 3.8.1 ACTIONS (continued) | AC Sources - Operating 3.8.1 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME G. Required Action and G.1 Be in MODE 3. | COMPLETION CONDITION REQUIRED ACTION TIME G. Required Action and G.1 Be in MODE 3. 6 hours associated Completion Time of Condition A, B, C, 0, E, AND or F not met. | ||
G.2 Bein MODE 5. | G.2 Bein MODE 5. 36 hours H. Three or more AC sources H.1 Enter LCO 3.0.3. Immediately inoperable. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE ~REQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance availability for each required offsite circuit. with the Surveillance Frequency Control Program (contlnueo) | SURVEILLANCE REQUIREMENTS SURVEILLANCE ~REQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance availability for each required offsite circuit. with the Surveillance Frequency Control Program (contlnueo) | ||
CALLAWAY PLANT 3.8-6 Amendment No. 202 | CALLAWAY PLANT 3.8-6 Amendment No. 202 | ||
| Line 2,667: | Line 2,601: | ||
~ 6201 kW for the entire test period if auto connected design loads are less than 6201 kW. | ~ 6201 kW for the entire test period if auto connected design loads are less than 6201 kW. | ||
Verify each DG operating at a power factor ~ 0.9 and In accordance | Verify each DG operating at a power factor ~ 0.9 and In accordance | ||
:2: 0.8 operates for :2 | :2: 0.8 operates for :2: 24 hours: | ||
* with the | * with the | ||
* Surveillance | * Surveillance | ||
: a. For :2 | : a. For :2: 2 hours loaded :2: 6600 kW and i Frequency | ||
~ 6821 kW; and Control Program | ~ 6821 kW; and Control Program | ||
: b. For the remaining hours of the test loaded | : b. For the remaining hours of the test loaded | ||
:2: 5580 kW and ~ 6201 kW. | :2: 5580 kW and ~ 6201 kW. | ||
SR 3.8.1.15 --------------------------- NOTE S ------------------------------- | SR 3.8.1.15 --------------------------- NOTE S ------------------------------- | ||
: 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated :2 | : 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated :2: 2 hours loaded :2: 5580 kW and | ||
~ 6201 kW. Momentary transients outside of load range do not invalidate this test. | ~ 6201 kW. Momentary transients outside of load range do not invalidate this test. | ||
: 2. All DG starts may be preceded by an engine prelube period. | : 2. All DG starts may be preceded by an engine prelube period. | ||
| Line 2,769: | Line 2,703: | ||
----------------------------------------------------------- NOTE ---------------------------------------------------------- | ----------------------------------------------------------- NOTE ---------------------------------------------------------- | ||
Separate Condition entry is allowed for each DG. | Separate Condition entry is allowed for each DG. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more DGs with fuel A.1 Restore fuel oil level to | COMPLETION CONDITION REQUIRED ACTION TIME A. One or more DGs with fuel A.1 Restore fuel oil level to 48 hours level < 80,900 gal and within limits. | ||
> 69,800 gal in storage tank. | > 69,800 gal in storage tank. | ||
B. One or more DGs with lube B.1 Restore lube oil | B. One or more DGs with lube B.1 Restore lube oil 48 hours oil inventory < 750 gal and inventory to within limits. | ||
> 686 gal. | > 686 gal. | ||
C. One or more DGs with C.1 Restore fuel oil total 7 days stored fuel oil total particulates within limit. | C. One or more DGs with C.1 Restore fuel oil total 7 days stored fuel oil total particulates within limit. | ||
| Line 2,780: | Line 2,714: | ||
Diesel Fuel Oil, Lube Oil. and Starting Air 3.8.3 ACTIONS (continued) | Diesel Fuel Oil, Lube Oil. and Starting Air 3.8.3 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME One or more DGs with two E.1 Restore two starting air | COMPLETION CONDITION REQUIRED ACTION TIME One or more DGs with two E.1 Restore two starting air 48 hours starting air receivers in receivers with pressure service with pressure 2:: 435 psig. | ||
< 435 psig and 2:: 250 psig. | < 435 psig and 2:: 250 psig. | ||
QB One or more DGs with only E.2 Restore one starting air | QB One or more DGs with only E.2 Restore one starting air 48 hours one starting air receiver in receiver with pressure service with pressure 2:: 610 psig. | ||
< 610 psig and 2:: 300 psig. | < 610 psig and 2:: 300 psig. | ||
F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable. | F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable. | ||
| Line 2,795: | Line 2,729: | ||
DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Train A and Train B DC electrical power subsystems shall be OPERABLE. | DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Train A and Train B DC electrical power subsystems shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One DC electrical power A.1 Restore DC electrical | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One DC electrical power A.1 Restore DC electrical 2 hours subsystem inoperable. power subsystem to OPERABLE status. | ||
B. Require Action and B.1 Be in MODE 3. | B. Require Action and B.1 Be in MODE 3. 6 hours Associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is ~ 130.2 V on float In accordance charge. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-25 Amendment No. 202 | ||
DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) | DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) | ||
| Line 2,836: | Line 2,770: | ||
Separate Condition entry is allowed for each battery. | Separate Condition entry is allowed for each battery. | ||
COMPLETION CONDITION REQUIRED ACTION TIME A One or more batteries with A1 Verify pilot cells 1 hour one or more battery cell electrolyte level and float parameters not within voltage meet Category A or B limits. Table 3.8.6-1 Category C limits. | COMPLETION CONDITION REQUIRED ACTION TIME A One or more batteries with A1 Verify pilot cells 1 hour one or more battery cell electrolyte level and float parameters not within voltage meet Category A or B limits. Table 3.8.6-1 Category C limits. | ||
AND A2 Verify battery cell | AND A2 Verify battery cell 24 hours parameters meet Table 3.8.6-1 Category C AND limits. | ||
Once per 7 days thereafter AND A3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6-1. | Once per 7 days thereafter AND A3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6-1. | ||
(continued) | (continued) | ||
| Line 2,869: | Line 2,803: | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One required inverter A.1 ------------ NOTE ---------- | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One required inverter A.1 ------------ NOTE ---------- | ||
inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any vital bus de-energized. | inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any vital bus de-energized. | ||
Restore inverter to 24 hours OPERABLE status. | |||
Restore inverter to | B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours CALLAWAY PLANT 3.8-34 Amendment No. 202 I | ||
B. Required Action and B.1 Be in MODE 3. | |||
Inverters - Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, and alignment to In accordance required AC vital buses. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-35 Amendment No. 202 | Inverters - Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, and alignment to In accordance required AC vital buses. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-35 Amendment No. 202 | ||
| Line 2,884: | Line 2,817: | ||
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies . | AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies . | ||
( continued) | ( continued) | ||
CALLAWAY PLANT 3.8-36 Amendment No. 202 I | |||
Inverters - Shutdown 3.8.8 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.2.3 Suspend operations Immediately inverters inoperable. involving positive (continued) reactivity additions that could result in loss of required SDM or boron concentration. | Inverters - Shutdown 3.8.8 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.2.3 Suspend operations Immediately inverters inoperable. involving positive (continued) reactivity additions that could result in loss of required SDM or boron concentration. | ||
| Line 2,892: | Line 2,825: | ||
Distribution Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems - Operating LCO 3.8.9 Train A and Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE. | Distribution Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems - Operating LCO 3.8.9 Train A and Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE. | ||
APPLICABILITY: MODES 1, 2, 3, and 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One AC electrical power A.1 Restore AC electrical | ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One AC electrical power A.1 Restore AC electrical 8 hours distribution subsystem power distribution inoperable. subsystem to OPERABLE status. | ||
16 hours from discovery of failure to meet LCO B. One AC vital bus B.1 Restore AC vital bus 2 hours subsystem inoperable. subsystem to OPERABLE status. | |||
16 hours from discovery of failure to meet LCO (continued) | |||
CALLAWAY PLANT 3.8-38 Amendment No. 202 I | CALLAWAY PLANT 3.8-38 Amendment No. 202 I | ||
Distribution Systems - Operating 3.8.9 ACTIONS (continued) | Distribution Systems - Operating 3.8.9 ACTIONS (continued) | ||
COMPLETION CONDITION REQUIRED ACTION TIME C. One DC electrical power C.1 Restore DC electrical | COMPLETION CONDITION REQUIRED ACTION TIME C. One DC electrical power C.1 Restore DC electrical 2 hours distribution subsystem power distribution inoperable. subsystem to OPERABLE status. | ||
16 hours from discovery of failure to meet LCO D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours E. Two trains with inoperable E.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function. | |||
SURVEILLANCE REQUIREMENTS SU RVEI LLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance required AC, DC, and AC vital bus electrical power with the distribution subsystems. Surveillance Frequency Control Program CALLAWAY PLANT 3.8-39 Amendment No. 202 | SURVEILLANCE REQUIREMENTS SU RVEI LLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance required AC, DC, and AC vital bus electrical power with the distribution subsystems. Surveillance Frequency Control Program CALLAWAY PLANT 3.8-39 Amendment No. 202 | ||
| Line 2,938: | Line 2,871: | ||
COMPLETION CONDITION REQUIRED ACTION TIME TIME A. NOTE A.1 Suspend CORE Immediately Required Action A.3 must ALTERATIONS. | COMPLETION CONDITION REQUIRED ACTION TIME TIME A. NOTE A.1 Suspend CORE Immediately Required Action A.3 must ALTERATIONS. | ||
be completed whenever Condition A is entered. AND One or more valves not A.2 Initiate actions to secure Immediately secured in closed position. valve in closed position. | be completed whenever Condition A is entered. AND One or more valves not A.2 Initiate actions to secure Immediately secured in closed position. valve in closed position. | ||
AND A.3 Perform SR 3.9.1.1. | AND A.3 Perform SR 3.9.1.1. 4 hours CALLAWAY PLANT 3.9-3 Amendment No. 181 | ||
Unborated Water Source Isolation Valves 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water In accordance sources is secured in the closed position. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-4 Amendment No. 202 | Unborated Water Source Isolation Valves 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water In accordance sources is secured in the closed position. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-4 Amendment No. 202 | ||
| Line 2,948: | Line 2,881: | ||
ANM A.2 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1. | ANM A.2 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1. | ||
B. Two required source range B.1 Initiate action to restore Immediately neutron flux monitors one source range inoperable, neutron flux monitor to OPERABLE status. | B. Two required source range B.1 Initiate action to restore Immediately neutron flux monitors one source range inoperable, neutron flux monitor to OPERABLE status. | ||
B.2 Perform SR 3.9.1.1. Once per | B.2 Perform SR 3.9.1.1. Once per 12 hours CALLAWAY PLANT 3.9-5 Amendment No. 181 I | ||
Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 --------------------------------- NOTE --------------------------- | Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 --------------------------------- NOTE --------------------------- | ||
| Line 2,961: | Line 2,894: | ||
: 2. capable of being closed by an OPERABLE Containment Purge Isolation valve. | : 2. capable of being closed by an OPERABLE Containment Purge Isolation valve. | ||
-- ---- -- NOTE --- ------ --- | -- ---- -- NOTE --- ------ --- | ||
Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls. | Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls. | ||
APPLICABILITY: During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment. | APPLICABILITY: During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment. | ||
| Line 2,975: | Line 2,907: | ||
RHR and Coolant Circulation - High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation. | RHR and Coolant Circulation - High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation. | ||
S- --------------- NOTE -----.-.--------.-----......--------- | S- --------------- NOTE -----.-.--------.-----......--------- | ||
The required RHR loop may be removed from operation for < 1 hour per 8 hour period, provided no operations are permitted that would cause introduction into the Reactor Coolant System, coolant with boron concentration less than that required to meet the minimum required boron concentration | The required RHR loop may be removed from operation for < 1 hour per 8 hour period, provided no operations are permitted that would cause introduction into the Reactor Coolant System, coolant with boron concentration less than that required to meet the minimum required boron concentration of LCO 3.9.1. ---- .. .. -- --. =- . . .. .- .... . ....- | ||
of | |||
LCO 3.9.1. ---- .. .. -- --. =- . . .. .- .... . .... | |||
APPLICABILITY: MODE 6 with the water level Ž_23 ft above the top of reactor vessel flange. | APPLICABILITY: MODE 6 with the water level Ž_23 ft above the top of reactor vessel flange. | ||
ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. RHR loop requirements not A.1 Suspend operations that Immediately met. would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1. | ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. RHR loop requirements not A.1 Suspend operations that Immediately met. would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1. | ||
| Line 2,989: | Line 2,916: | ||
RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RHR loop requirements not A.3 Initiate action to satisfy Immediately met. RHR loop requirements. | RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RHR loop requirements not A.3 Initiate action to satisfy Immediately met. RHR loop requirements. | ||
(continued) | (continued) | ||
AND AA Close all containment | AND AA Close all containment 4 hours penetrations providing direct access from containment atmosphere to outside atmosphere. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance reactor coolant at a flow rate of 2 1000 gpm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-10 Amendment 202 | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance reactor coolant at a flow rate of 2 1000 gpm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-10 Amendment 202 | ||
| Line 3,002: | Line 2,929: | ||
COMPLETION CONDITION REQUIRED ACTION TIME B. No RHR loop in operation. B.1 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LeO 3.9.1. | COMPLETION CONDITION REQUIRED ACTION TIME B. No RHR loop in operation. B.1 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LeO 3.9.1. | ||
AND B.2 Initiate action to restore Immediately one RHR loop to operation. | AND B.2 Initiate action to restore Immediately one RHR loop to operation. | ||
AND B.3 Close all containment | AND B.3 Close all containment 4 hours penetrations providing direct access from containment atmosphere to outside atmosphere. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating In accordance reactor coolant at a flow rate of?: 1000 gpm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-12 Amendment No. 202 | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating In accordance reactor coolant at a flow rate of?: 1000 gpm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-12 Amendment No. 202 | ||
| Line 3,046: | Line 2,973: | ||
CALLAWAY PLANT 5.0-1 Amendment 173 | CALLAWAY PLANT 5.0-1 Amendment 173 | ||
Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant. | Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant. | ||
: a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications shall be documented in the FSAR; | : a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications shall be documented in the FSAR; | ||
| Line 3,057: | Line 2,983: | ||
CALLAWAY PLANT 5.0-2 Amendment No. 155 | CALLAWAY PLANT 5.0-2 Amendment No. 155 | ||
Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) exceed | Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) exceed 2 hours in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements. | ||
c A Radiation Protection Department technician shall be on site when fuel is in the reactor. The position may be vacant for not more than | c A Radiation Protection Department technician shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours. in order to provide for unexpected absence, provided immediate action is taken to fill the required position. | ||
: d. Not Used | : d. Not Used | ||
: e. The operations manager or assistant operations manager shall hold an SRO license. | : e. The operations manager or assistant operations manager shall hold an SRO license. | ||
| Line 3,092: | Line 3,018: | ||
CALLAWAY PLANT 5.0-6 Amendment No. 155 | CALLAWAY PLANT 5.0-6 Amendment No. 155 | ||
Programs and Manuals 5.5 | Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the recirculation portion of the Containment Spray, Safety Injection, Chemical and Volume Control, and Residual Heat Removal. The program shall include the following: | ||
5.5 Programs and Manuals (continued) 5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the recirculation portion of the Containment Spray, Safety Injection, Chemical and Volume Control, and Residual Heat Removal. The program shall include the following: | |||
: a. Preventive maintenance and periodic visual inspection requirements; and | : a. Preventive maintenance and periodic visual inspection requirements; and | ||
: b. Integrated leak test requirements for each system at refueling cycle intervals or less. | : b. Integrated leak test requirements for each system at refueling cycle intervals or less. | ||
| Line 3,417: | Line 3,341: | ||
3-2 | 3-2 | ||
4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates or could result in significant environmental impact casually related to plant operation shall be recorded and reported to the NRC within 24 hours followed by a written report per Subsection 5.4.2. The following are examples: excessive bird impaction events, onsite plant or animal disease outbreaks, mortality or unusual occur-rence of any species protected by the Endangered Species Act of 1973, fish kills, increase in nuisance organisms or conditions, and unanticipated or emergency discharge of waste water or chemical substances. | |||
4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates or could result in significant environmental impact casually related to plant operation shall be recorded and reported to the NRC within | |||
No routine monitoring programs are required to implement this condition. | No routine monitoring programs are required to implement this condition. | ||
4.2 Aerial Remote Sensing Vegetative communities of the site and vicinity within 1 kilometer of the cooling towers in all directions shall be-aerially photographed to detect and - | 4.2 Aerial Remote Sensing Vegetative communities of the site and vicinity within 1 kilometer of the cooling towers in all directions shall be-aerially photographed to detect and - | ||
Latest revision as of 15:18, 9 March 2020
| ML15062A052 | |
| Person / Time | |
|---|---|
| Site: | Callaway  |
| Issue date: | 03/06/2015 |
| From: | Division of License Renewal |
| To: | |
| Shared Package | |
| ML14302A286 | List: |
| References | |
| Download: ML15062A052 (384) | |
Text
TECHNICAL SPECIFICATIONS FOR CALLA WA Y PLANT DOCKET NO. 50-483
'ADmSw UF
TABLE OF CONTENTS 1.0 USE AND APPLICATION ........................................................................ 1.1-1 1.1 Definitions .......................................................................................... 1.1-1 1.2 Logical Connectors ............................................................................ 1.2-1 1.3 Completion Times .............................................................................. 1.3-1 1.4 Frequency .......................................................................................... 1.4-1 2.0 SAFETY LIMITS (SLs) ..........................................................................2.0-1 2.1 SLs ...................................................................................................2.0-1 2.2 SL Violations ....................................................................................2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ..... 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY .................... 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS .....................................................3.1-1 3.1.1 SHUTDOWN MARGIN (SDM) ........................................................3.1-1 3.1.2 Core Reactivity ...............................................................................3.1-2 3.1.3 Moderator Temperature Coefficient (MTC) ...................................... 3.1-4 3.1.4 Rod Group Alignment Limits ......................................:..................... 3.1-7 3.1.5 Shutdown Bank Insertion Limits .....................................................3.1-11 3.1.6 Control Bank Insertion Limits ........................................................... 3.1-13 3.1.7 Rod Position Indication .................................................................... 3.1-16 3.1.8 PHYSICS TESTS Exceptions - MODE 2 ........................................ 3.1-19 3.1.9 RCS Boron Limitations < 500°F ....................................................... 3.1-22 3.2 POWER DISTRIBUTION LIMITS .........................................................3.2-1 3.2.1 Heat Flux Hot Channel Factor (Fa(Z>>
(Fa Methodology) ......................................................................3.2-1 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor ................................... 3.2-6 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology) .................................................. 3.2-9 3.2.4 QUADRANT POWER TILT RATIO (QPTR) ................................... 3.2-10 3.3 INSTRUMENTATION ............................................................................3.3-1 3.3.1 Reactor Trip System (RTS) Instrumentation ...................................3.3-1 3.3.2 Engineered Safety Feature Actuation System (ESFAS)
Instrumentation .......................................................................... 3.3-27 3.3.3 Post Accident Monitoring (PAM) Instrumentation ............................3.3-51 3.3.4 Remote Shutdown System ............................................................. 3.3-56 CALLAWAY PLANT Amendment 202
TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation .......................................................................... 3.3-59 3.3.6 Containment Purge Isolation Instrumentation ................................. 3.3-61 3.3.7 Control Room Emergency Ventilation System (CREVS)
Actuation Instrumentation ......................................................... 3.3-67 3.3.8 Emergency Exhaust System (EES) Actuation Instrumentation ......................................................................... 3.3-73 3.3.9 Boron Dilution Mitigation System (BDMS) ...................................... 3.3-79 3.4 REACTOR COOLANT SYSTEM (RCS) ................................................ 3.4-1 3.4.1 RCSPressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits ................................................... 3.4-1 3.4.2 RCS Minimum Temperature for Criticality ....................................... 3.4-3 3.4.3 RCS Pressure and Temperature (prr) Limits .................................. 3.4-4 3.4.4 RCS Loops - MODES 1 and 2 ......................................................... 3.4-6 3.4.5 RCS Loops - MODE 3 ..................................................................... 3.4-7 3.4.6 RCS Loops - MODE 4 ..................................................................... 3.4-10 3.4.7 RCS Loops - MODE 5, Loops Filled ................................................ 3.4-12 3.4.8 RCS Loops - MODE 5, Loops Not Filled ......................................... 3.4-15 3.4.9 Pressurizer ....................................................................................... 3.4-17 3.4.10 Pressurizer Safety Valves ................................................................ 3.4-19 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) ...................... 3.4-21 3.4.12 Cold Overpressure Mitigation System (COMS) ............................... 3.4-25 3.4.13 RCS Operational LEAKAGE ............................................................ 3.4-30 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage ................................ 3.4-32 3.4.15 RCS Leakage Detection Instrumentation ........................................ 3.4-36 3.4.16 RCS Specific Activity ....................................................................... 3.4-40 3.4.17 Steam Generator (SG) Tube Integrity .............................................. 3.4-43 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) ........................... 3.5-1 3.5.1 Accumulators ................................................................................... 3.5-1 3.5.2 ECCS - Operating ........................................................................... 3.5-4 3.5.3 ECCS - Shutdown ............................................................................ 3.5-7 3.5.4 Refueling Water Storage Tank (RWST) ......................................... 3.5-9 3.5.5 Seal Injection Flow ........................................................................... 3.5-11 3.6 CONTAINMENT SYSTEMS .................................................................. 3.6-1 3.6.1 Containment ................................................................................... 3.6-1 3.6.2 Containment Air Locks ..................................................................... 3.6-3 3.6.3 Containment Isolation Valves ......................................................... 3.6-7 CALLAWAY PLANT 2 Amendment 202
TABLE OF CONTENTS 3.6 CONTAINMENT SYSTEMS (continued) 3.6.4 Containment Pressure ..................................................................... 3.6-16 3.6.5 Containment Air Temperature ......................................................... 3.6-17 3.6.6 Containment Spray and Cooling Systems ...................................... 3.6-18 3.6.7 Recirculation Fluid pH Control (RFPC) System ............................... 3.6-21 3.7 PLANT SYSTEMS ................................................................................. 3.7-1 3.7.1 Main Steam Safety Valves (MSSVs) ............................................... 3.7-1 3.7.2 Main Steam Isolation Valves (MSIVs). Main Steam Isolation Valve Bypass Valves (MSIVBVs), and Main Steam Low Point Drain Isolation Valves (MSLPDIVs) ................................. 3.7-5 3.7.3' Main Feedwater Isolation Valves (MFIVs), Main Feedwater Regulating Valves (MFRVs). and Main Feedwater Regulating Valve Bypass Valves (MFRVBVs) .............................................. 3.7-9 3.7.4 AtmospheriC Steam Dump Valves (ASDs) ...................................... 3.7-12 3.7.5 Auxiliary Feedwater (AFW) System ................................................. 3.7-15 3.7.6 Condensate Storage Tank (CST) .................................................... 3.7-19 3.7.7 Component Coaling Water (CCW) System ..................................... 3.7-21 3.7.8 Essential Service Water System (ESW) .......................................... 3.7-23 3.7.9 Ultimate Heat Sink (UHS) ................................................................ 3.7-26 3.7.10 Control Room Emergency Ventilation System (CREVS) ................. 3.7-28 3.7.11 Control Room Air Conditioning System (CRACS) ........................... 3.7-32 3.7.12 Not Used .......................................................................................... 3.7-35 3.7.13 Emergency Exhaust System (EES) ................................................. 3.7-36 3.7.14 Not Used .......................................................................................... 3.7-39 3.7.15 Fuel Storage Pool Water Level ........................................................ 3.7-40 3.7.16 Fuel Storage Pool Boron Concentration .......................................... 3.7-41 3.7.17 Spent Fuel Assembly Storage ......................................................... 3.7-43 3.7.18 Secondary Specific Activity .............................................................. 3.7-45 3.7.19 Secondary System Isolation Valves (SSIVs) ................................... 3.7-46 3.8 ELECTRICAL POWER SYSTEMS ........................................................ 3.8-1 3.8.1 AC Sources - Operating ................................................................... 3.8-1 3.8.2 AC Sources - Shutdown .................................................................. 3.8-18 3.8.3 Diesel Fuel Oil, Lube 011, and Starting Air ....................................... 3.8-22 3.8.4 DC Sources - Operating .................................................................. 3.8-25 3.8.5 DC Sources - Shutdown .................................................................. 3.8-28 3.8.6 Battery Cell Parameters ................................................................... 3.8-30 3.8.7 Inverters - Operating ........................................................................ 3.8-34 3.8.8 Inverters - Shutdown ........................................................................ 3.8-36 3.8.9 Distribution Systems - Operating ..................................................... 3.8-38 CALLAWAY PLANT 3 Amendment 202
TABLE OF CONTENTS 3.8 ELECTRICAL POWER SYSTEMS (continued) 3.8.10 Distribution Systems - Shutdown ..................................................... 3.8-40 3.9 REFUELING OPERATIONS ................................................................. 3.9-1 3.9.1 Boron Concentration ........................................................................ 3.9-1 3.9.2 Unborated Water Source Isolation Valves ....................................... 3.9-3 3.9.3 Nuclear Instrumentation ................................................................... 3.9-5 3.9.4 Containment Penetrations ............................................................... 3.9-7 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level ................................................... 3.9-9 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level .................................................... 3.9-11 3.9.7 Refueling Pool Water Level ............................................................. 3.9-14 4.0 DESIGN FEATURES ............................................................................... 4.0-1 4.1 Site Location .................................................................................... 4.0-1 4.2 Reactor Core ................................................................................... 4.0-1 4.3 Fuel Storage .................................................................................... 4.0-1 5.0 ADMINISTRATIVE CONTROLS ........................................................... 5.0-1 5.1 Responsibility ................................................................................... 5.0-1 5.2 Organization .................................................................................... 5.0-2 5.3 Unit Staff Qualifications ................................................................... 5.0-4 5.4 Procedures ...................................................................................... 5.0-5 5.5 Programs and Manuals ..................................................................... 5.0-6 5.6 Reporting Requirements .................................................................. 5.0-22 5.7 High Radiation Area ......................................................................... 5.0-27 CALLAWAY PLANT 4 Amendment 202
Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions go- -------- I- i---------NOTE ---- --- a- -- a-A -----
The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.
Term Definition, ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.
ACTUATION LOGIC TEST An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state required for OPERABILITY of a logic circuit and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices.
AXIAL FLUX DIFFERENCE AFD shall be the difference in normalized flux signals (AFD) between the top and bottom halves of an excore neutron detector.
CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps.
CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.
(continued)
CALLAWAY PLANT 1.1-1 Amendment No. 135 MAR 2 7 2CO
Definitions 1.1 1.1 Definitions (continued)
CHANNEL OPERATIONAL A COT shall be the injection of a simulated or actual signal TEST (COT) into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints required for channel OPERABILITY such that the setpoints are within the necessary range and accuracy. The COT may be performed by means of any series of sequential, overlapping, or total channel steps.
CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel.
Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.
CORE OPERATING LIMITS The COLR is the unit specific document that provides cycle REPORT (COLR) specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.
DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes 1-131, 1-132,1-133,1-134, and 1-135 actually present.
The determination of DOSE EQUIVALENT 1-131 shall be performed using thyroid dose conversion factors from:
- 1. Table III of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites," or
- 2. Table E-7 of Regulatory Guide 1.109, Revision 1, NRC, 1977, or
- 3. International Commission on Radiological Protection (ICRP) Publication 30, "Limits for Intakes of Radionuclides by Workers," Supplement to Part 1, pages 192-212, Table titled "Committed Dose Equivalent in Target Organs or Tissues per Intake of Unit Activity," 1979, or
- 4. Table 2.1 of EPA Federal Guidance Report No. 11, EPA-
- 520/1-88-020, "Limiting Values of Radionuclide Intake -
and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1988.
(continued)
CALLAWAY PLANT 1.1-2 Amendment 178
Definitions 1.1 1.1 Definitions (continued)
DOSE EQUIVALENT XE-133 DOSE EQUIVALENT XE-133 shall be that concentration of Xe-133 (microcuies per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-87, Kr-88, Xe-133m, Xe-133, Xe-135m, Xe-135, and Xe-138 actually present. If a specific noble gas nuclide is not detected, it should be assumed to be present at the minimum detectable activity.
The determination of DOSE EQUIVALENT XE-133 shall be performed using the effective dose conversion factors for air submersion listed in Table I11.1 of EPA Federal Guidance Report No. 12, EPA-402-R-93-081, "External Exposure to Radionuclides in Air, Water, and Soil", 1993.
ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time interval from FEATURE (ESF) RESPONSE when the monitored parameter exceeds its ESF actuation TIME setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.
LEAKAGE LEAKAGE shall be:
- a. Identified LEAKAGE
- 1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water leakoff), that is captured and conducted to collection systems or a sump or collecting tank;
- 2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or'not to be pressure boundary LEAKAGE; or
- 3. Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE);
(continued) 1.1-3 Amendment 178 CALLAWAY PLANT PLANT 1.1-3 Amendment 178
Definitions 1.1 1.1 Definitions LEAKAGE (continued) b. Unidentified LEAKAGE All LEAKAGE (except RCP seal water leakoff) that is not identified LEAKAGE;
- c. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.
MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing all master relays in the channel required for channel OPERABILITY and verifying the OPERABILITY of each required master relay. The MASTER RELAY TEST shall include a continuity check of each associated required slave relay. The MASTER RELAY TEST may be performed by means of any series of sequential, overlapping, or total steps.
MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.
OPERABLE - OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).
PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation. These tests are:
- a. Described in Chapter 14 of the FSAR;
- b. Authorized under the provisions of 10 CFR 50,59; or
- c. Otherwise approved by the Nuclear Regulatory Commission.
(continued)
CALLAWAY PLANT 1.1-4 Amendment 178 I
Definitions 1.1 1.1 Definitions (continued)
PRESSURE AND The PTLR is the unit specific document that provides the TEMPERATURE LIMITS reactor vessel pressure and temperature limits, including REPORT (PTLR) heatup and REPORT (PTLR) cooldown rates, the power operated relief valve (PORV) lift settings, and the Cold Overpressure Mitigation System (COMS) arming temperature, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.6.
QUADRANT POWER QPTR shall be the ratio of the maximum upper excore TILT RATIO (QPTR) detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.
RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of 3565 MWt.
REACTOR TRIP SYSTEM The RTS RESPONSE TIME shall be that time interval from (RTS) RESPONSE TIME when the monitored parameter exceeds its RTS trip setpoint at the channel sensor until loss of stationary gripper coil voltage. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.
SHUTDOWN MARGIN (SDM) SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:
- a. All rod duster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and
- b. In MODES 1 and 2, the fuel and moderator temperatures
-- --are changed to the hot zero-power temperatures.- -
(conunuea)
CALLAWAY PLANT 1.1-5 Amendment 178 I
Definitions 1.1 1.1 Definitions (continued)
SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing all slave relays in the channel required for channel OPERABILITY and verifying the OPERABILITY of each required slave relay. The SLAVE RELAY TEST shall include a continuity check of associated required testable actuation devices. The SLAVE RELAY TEST may be performed by means of any series of sequential, overlapping, or total steps.
STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.
THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.
TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip actuating device OPERATIONAL TEST and verifying the OPERABILITY of all devices in the channel (TADOT) required for trip actuating device OPERABILITY. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the necessary accuracy. The TADOT may be performed by means of any series of sequential, overlapping, or total channel steps.
CALLAWAY PLANT 1.1-6 Amendment 178 I
Definitions 1.1 Table 1.1-1 (page 1 of 1)
MODES AVERAGE REACTIVITY % RATED REACTOR COOLANT MODE TITLE CONDITION THERMAL TEMPERATURE (ky) POWERea) (OF) 1 Power Operation 2 0.99 >5 NA 2 Startup 20.99 S 5 NA 3 Hot Standby < 0.99 NA 2 350 4 Hot Shutdown(b) < 0.99 NA 350 > T.-V > 200 5 Cold Shutdownb) < 0.99 NA
- 200 6 Refueling(') NA NA NA (a) Excluding decay heat.
(b) At least 53 of 54 reactor vessel head closure bolts fully tensioned.
(c) Two or more reactor vessel head closure bolts less than fully tensioned.
CALLAWAY PLANT 1.1-7 Amendment No. 133
Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.
Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.
BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action).
The successive levels of logic are identified by additional digits of the Required Action number and by successive indentations of the logical connectors.
When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.
(continued)
CALLAWAY PLANT 1.2-1 Amendment No. 133
Logical Connectors 1.2 1.2 Logical Connectors (continued)
EXAMPLES The following examples illustrate the use of logical connectors.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. LCO not met. A.1 Verify...
AND A.2 Restore...
In this example the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.
(continued)
CALLAWAY PLANT 1 .2-2 Amendment No. 133
Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-2 (continued)
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. LCO not met. A.1 Trip ...
OR A.2.1 Verify...
AND A.2.2.1 Reduce...
OR A.2.2.2 Perform ...
OR A.3 Align ...
This example represents a more complicated use of logical connectors.
Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connectorAND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.
CALLAWAY PLANT 1.2-3 Amendment No. 133
Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.
BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).
DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.
If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.
Once a Condition has been entered, subsequent trains, subsystems, components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition, unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition.
However, when a subseauent train, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:
(continued)
CALLAWAY PLANT 1.3-1 Amendment No. 133
Completion Times 1.3 1.3 Completion Times DESCRIPTION a. Must exist concurrent with the first inoperability; and (continued)
- b. Must remain inoperable or not within limits after the first inoperability is resolved.
The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either.
- a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />; or
- b. The stated Completion Time as measured from discovery of the subsequent inoperability.
The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.
The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery. . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.
(continued)
CALLAWAY PLANT 1.3-2 Amendment No. 133
Completion Times 1.3 1.3 Completion Times (continued)
EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.
EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMTIEON B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.
The Required Actions of Condition B are to be in MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND in MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. A total of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (not 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br />) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />, the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days <br />0.00917 hours <br />5.456349e-5 weeks <br />1.25565e-5 months <br /> because the total time allowed for reaching MODE 5 is 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
If Condition B is entered while in MODE 3, the time allowed for reaching MODE 5 is the next 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
(continued)
CALLAWAY PLANT 1.3-3 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.
B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> When a pump is declared inoperable, Condition A is entered. If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated.
When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.
While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO'3.0.3 may be exited and operation continued in accordance with Condition A.
While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with (continued)
CALLAWAY PLANT 1.3-4 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)
Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.
On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for > 7 days.
(continued)
CALLAWAY PLANT 1.3-5 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore Function X 7 days Function X train to OPERABLE train status. AND inoperable.
10 days from discovery of failure to meet the LCO B. One B.1 Restore Function Y 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Function Y train to OPERABLE train status. AND inoperable.
10 days from discovery of failure to meet the LCO C. One C.1 Restore Function X 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Function X train to OPERABLE train status.
OR AND C.2 Restore Function Y 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> One train to OPERABLE Function Y status.
train inoperable.
(continued)
CALLAWAY PLANT 1.3-6 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)
When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was declared inoperable (i.e., the time the situation described in Condition C was discovered).
If Required Action C.2 is completed within the specified Completion Time, Conditions B and C are exited. Ifthe Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A).
The Completion Times of Conditions A and B are modified by a logical connector with a separate 10 day Completion Time measured from the time itwas discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.
(continued)
CALLAWAY PLANT 1.3-7 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One or more A.1 Restore valve(s) to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> valves OPERABLE status.
B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.
Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
If the Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> (including the extension) expires while one or more valves are still inoperable, Condition B is entered.
(continued)
CALLAWAY PLANT 1.3-8 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)
ACTIONS NOTE Separate Condition entry is allowed for each inoperable valve.
CONDITION REQUIRED ACTION COMPLETION A. One or more A.1 Restore valve to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> valves OPERABLE status.
B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.
The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.
(continued)
CALLAWAY PLANT 1.3-9 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)
If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.
Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.
EXAMPLE 1.3-6 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per inoperable. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> OR A.2 Reduce THERMAL 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> POWER to I
< 50% RTP.
B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated Completion Time not met.
(continued)
CALLAWAY PLANT 1.3-10 Amendment No. 135 MAR, 2 7 200
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)
Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2),
Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> is not met, Condition B is entered.
If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.
(continued)
CALLAWAY PLANT 1.3-1 1 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)
ACTIONS CONDITION REQUIRED ACTION C IMPMETION A. One A.1 Verify affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> subsystem subsystem isolated.
inoperable. AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter AND A.2 Restore subsystem to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter" interval begins upon performance of Required Action A.1.
If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or any subsequent 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Tme clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with (continued)
CALLAWAY PLANT 1.3-1 2 Amendment No. 133
Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)
Condition A, provided the Completion Time for Required Action A.2 has not expired.
IMMEDIATE When "Immediately" is used as a Completion Time, the Required COMPLETION Action should be pursued without delay and in a controlled manner.
TIME CALLAWAY PLANT 1.3-1 3 Amendment No. 133
Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.
DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.
The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR)
Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR as well as certain Notes in the Surveillance column that modify performance requirements.
Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.
(continued)
CALLAWAY PLANT 1.4-1 Amendment No. 133
Frequency 1.4 1.4 Frequency (continued)
EXAMPLES The following examples illustrate the various ways that Frequencies are specified. Inthese examples, the Applicability of the LCO (LCO not shown) is MODES 1,2, and 3.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.
If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4.
(continued)
CALLAWAY PLANT 1.4-2 Amendment No. 133
Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-2 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
+
Verify flow is within limits. Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 2 25% RTP AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level
< 25% RTP to 2 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND").
This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2. 'Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to
< 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.
(continued)
CALLAWAY PLANT 1.4-3 Amendment No. 133
Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY NOTE Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 2 25% RTP.
Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is < 25% RTP between performances.
As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after power reaches 2 25% RTP to perform the Surveillance.
The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was
< 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> with power 2 25% RTP.
Once the unit reaches 25% RTP, 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.
CALLAWAY PLANT 1.4-4 Amendment No. 133
SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in the COLR; and the following SLs shall not be exceeded:
2.1.1.1 The design limit departure from nucleate boiling ratio (DNBR) shall be maintained > 1.22 for transients analyzed using the revised thermal design procedure (RTDP) methodology and the WRB-2 DNB correlation. For non-RTDP transients analyzed using the standard thermal design procedure, the DNBR shall be maintained greater than or equal to the applicable DNB correlation limit (> 1.17 for WRB-2, > 1.30 for W-3).
2.1.1.2 The peak fuel centerline temperature shall be maintained < 50800 F, decreasing by 580 F per 10,000 MWd/MTU of burnup.
2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5, the RCS pressure shall be;maintained <2735 psig.
2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
2.2.2 If SL 2.1.2 is violated:
2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
2.2.2.2 In MODE 3, 4, or 5, restore compliance within 5 minutes.
CALLAWAY PLANT 2.0-1 Amendment 183
LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2, LCO 3.0.7, and LCO 3.0.8. I LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.
Ifthe LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated.
LCO 3.0.3 When an'LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, In:
- a. MODE 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />;
- b. MODE 4 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />; and
- c. MODE 5 within 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br />.
Exceptions to this Specification are stated in the individual Specifications.
Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.
LCO 3.0.3 is only applicable in MODES 1, 2,3, and 4 (continued)
CALLAWAY PLANT 3.0-1 Amendment 179
LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)
LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:
- a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; or
- b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications; or
- c. When an allowance is stated in the individual value, parameter, or other Specification.
This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.
LCO 3.0.5 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 LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.
LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with Specification 5.5.15, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.
When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.
(continued)
CALLAWAY PLANT 3.0-2 Amendment No. 164
LCO Applicability 3.0 3.0 LCO APPLICABI~LY (continued)
LCO 3.0.7 Test Exception LCO 3.1.8 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with a Test Exception LCO is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.
LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and:
- a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />s: or
- b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem-supported system and are able to perform their associated support function within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared not met.
CALLAWAY PLANT 3.0-3 Amendment 179
SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT1 (513) APPLICABI1LITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR.
Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on Inoperable equipment or variables outside specified limits.
SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specifieo in the Frequency. as measured from the previous performance or as measured from th -time a specified condition of the Frequency is met.
For Frequencies specified as "once," the above interval extension does not apply.
If a Completion Time requires periodic performance on a "once per..."
basis, the above Frequency extension applies to each performance after the initial performance.
Exceptions to this Specification are stated in the individual Specifications.
SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and the risk impact shall be managed.
If the Surveillance Is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.
When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.
(continued)
CALLAWAY PLANT 3.0-4 Amendment No. 147 FEB OS m
SR Applicability 3.0 3.0 SR APPLICABILITY (continued)
SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.
This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.
CALLAWAY PLANT 3.0-5 Amendment No.164
SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)
LCO 3.1.1 SDM shall be within the limits provided in the COLR.
APPLICABILITY: MODE 2 with keff < 1.0, MODES 3, 4, and 5.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. SDM not within limit. A.1 Initiate boration to 15 minutes restore SDM to within limit.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-1 Amendment No. 202
Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within + I% Ak/k of predicted values.
APPLICABILITY: MODES I and 2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. Measured core reactivity A.1 Re-evaluate core design 7 days not within limit. and safety analysis, and determine that the reactor core is acceptable for continued operation.
AND A.2 Establish appropriate 7 days operating restrictions and SRs.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
CALLAWAY PLANT 3.1-2 Amendment No. 133
Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 ----------------------------- NOTE -------------------------------
The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.
Verify measured core reactivity is within +/-1 % L'lk/k of Once prior to predicted values. entering MODE 1 after each refueling
NOTE-------
Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-3 Amendment No. 202
MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC)
LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be that specified in Figure 3.1.3-1.
APPLICABILITY: MODE 1 and MODE 2 with kff 2 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. MTC not within upper limit. A.1 Establish administrative 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> withdrawal limits for control banks to maintain MTC within limit.
B. Required Action and B.1 Be in MODE 2 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion k,,, < 1.0.
Time of Condition A not met.
C. MTC not within lower limit. C.1 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.1-4 Amendment No. 133
MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE I after each refueling SR 3.1.3.2 NOTES
- 1. Not required to be performed until 7 effective full power days (EFPD) after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm.
- 2. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.
- 3. SR 3.1.3.2 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of s 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COLR.
Verify MTC is within lower limit. Once each cycle CALLAWAY PLANT 3.1-5 Amendment No. 133
MTC 3.1.3 7 I-I I I UL I LL J I]-L--
tub M OPERATI 1-1 J-H-1 (70%, 5.0)
I I III I I HII HIM KI II-V. H IM 11111, _H I--
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0a
_111111 HIM J LLLL_____1 I
- 0. It ACCE LE OPE
[T I I HIM HIM III-II 11111 T I 11 I N il
-A I 1 J-111, I I I Iff VII I I A I I
-111 - I JILL-L Tl 1.I 1. HIL 1I I 1 01 I I I I I I I I I I I I I I I I I I I I I I I I I I II II II I Iii. I II 'I ' I I -
0 10 - 20 30 40 50 60 70 80 9U LUU PERCENT OF RATED THERMAL POWER Figure 3.1.3-1 (page 1 of 1)
Moderator Temperature Coefficient vs. Power Level CALLAWAY PLANT 3.1-6 Amendment No. 133
Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE.
AND Individual indicated rod positions shall be within 12 steps of their group step counter demand position.
APPLICABILITY: MODES 1 and 2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One or more rod(s) A.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. the limits provided in the COLR.
OR A.1.2 Initiate boration to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> SDM to within limit.
AND A.2 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (continued)
CALLAWAY PLANT 3.1-7 Amendment No. 133
Rod Group Alignment Limits 3.1.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION
_ _ _ _ _ _ __ _ _ _ __ _ _ _TIM E B. One rod not within B.1 Restore rod to within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> alignment limits. alignment limits.
OR B.2.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the limits provided in the COLR.
OR B.2.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.
AND B.2.2 Reduce THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> POWER to
- 75% RTP.
AND B.2.3 Verify SDM to be within Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> the limits provided in the COLR.
AND B.2.4 Perform SR 3.2.1.1 and 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> SR 3.2.1.2.
AND B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (continued)
CALLAWAY PLANT 3.1-8 Amendment No. 133
Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION B. (continued) B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition B not met.
D. More than one rod not D.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within alignment limit. the limits provided in the COLR.
OR D.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore required SDM to within limit.
AND D.2 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> CALLAWAY PLANT 3.1-9 Amendment No. 133
Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. In accordance with the Surveillance Frequency Control Program SR 3.1.4.2 Verify rod freedom of movement (trippability) by In accordance moving each rod not fully inserted in the core with the
~ 10 steps in either direction. Surveillance Frequency Control Program SR 3.1.4.3 Verify rod drop time of each rod, from the fully Prior to reactor withdrawn position, is:5 2.7 seconds from the criticality after beginning of decay of stationary gripper coil voltage each removal of to dashpot entry, with: the reactor head
- a. Tavg ~ 500°F; and
- b. All reactor coolant pumps operating.
CALLAWAY PLANT 3.1-10 Amendment No. 202
Shutdown Bank Insertion Limits 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.5 Each shutdown bank shall be within insertion limits specified in the COLR.
APPLICABILITY: MODE 1, MODE 2 with any control bank not fully inserted.
NOTE This LCO is not applicable while performing SR 3.1.4.2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> banks not within limits. the limits provided in the COLR.
OR A.1.2 Initiate boration to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> SDM to within limit.
AND A.2 Restore shutdown banks 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to within limits.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
CALLAWAY PLANT 3.1-11 Amendment No. 133
Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the limits In accordance specified in the COLR. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-12 Amendment No. 202
Control Bank Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Control Bank Insertion Limits LCO 3.1.6 Control banks shall be within the insertion, sequence, and overlap limits specified in the COLR.
APPLICABILITY: MODE 1, MODE 2 with keff 2 1.0.
I I #%9I IML j l r-This LCO is not applicable while performing SR 3.1.4.2.
ACTIONS CONDITION REQUIRED ACTION TIME A. Control bank insertion A.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits not met. the limits provided in the COLR.
OR A.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.
AND A.2 Restore control bank(s) 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to within limits.
(continued)
CALLAWAY PLANT 3.1-13 Amendment No. 133
Control Bank Insertion Limits 3.1.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Control bank sequence or B.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> overlap limits not met. the limits provided in the COLR.
OR B.1.2 Initiate boration to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> SDM to within limit.
AND B.2 Restore control bank 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> sequence and overlap to within limits.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is within Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> the limits specified in the COLR. prior to achieving criticality SR 3.1.6.2 Verify each control bank insertion is within the limits In accordance specified in the COLR. with the Surveillance Frequency Control Program (Continued)
CALLAWAY PLANT 3.1-14 Amendment No. 202
Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.1.6.3 Verify sequence and overlap limits specified in the In accordance COLR are met for control banks not fully withdrawn with the from the core. Surveillance Frequency Control Program CALLAWAY PLANT 3.1-15 Amendment No. 202
Rod Position Indication 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication LCO 3.1.7 The Digital Rod Position Indication (DRPI) System and the Demand Position Indication System shall be OPERABLE.
APPLICABILITY: MODES 1 and 2.
ACTIONS
NOTE-------------------------------
Separate Condition entry is allowed for each inoperable rod position indicator and each demand position indicator.
COMPLETION CONDITION REQUIRED ACTION TIME TIME A. One DRPI per group A.1 Verify the position of the Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> inoperable for one or more rods with inoperable groups. position indicators indirectly by using core power distribution measurement information.
OR A.2 Reduce THERMAL 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> POWER to
- 50% RTP.
(continued)
CALLAWAY PLANT 3.1-16 Amendment No. 182
Rod Position Indication 3.1.7 ACTIONS (continued)
COMPLETION REQUIRED ACTION TIME CONDITION TIME B. More than one DRPI per B.1 Place the control rods Immediately group inoperable for one or under manual control.
more groups.
AND B.2 Monitor and record RCS Once per 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Tavg.
AND B.3 Verify the position of the Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> rods with inoperable position indicators indirectly by using core power distribution' measurement information.
AND B.4 Restore inoperable 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> position indicators to OPERABLE status such that a maximum of one DRPI per group is inoperable.
C. One or more rods with C.1 Verify the position of the 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> inoperable DRPIs have rods with inoperable been moved in excess of 24 position indicators steps in one direction since indirectly by using core the last determination of the power distribution rod's position. measurement information.
OR C.2 Reduce THERMAL 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> POWER to _ 50% RTP.
(continued)
CALLAWAY PLANT 3.1-17 Amendment No. 182
Rod Position Indication 3.1.7 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION D. One demand position D.1.1 Verify by administrative Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> indicator per bank means all DRPls for the inoperable for one or more affected banks are banks. OPERABLE.
AND D.1.2 Verify the most Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> withdrawn rod and the least withdrawn rod of the affected banks are
- 12 steps apart.
OR D.2 Reduce THERMAL 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> POWER to s 50% RTP.
E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the group Once prior to demand position for the full indicated range of rod criticality after travel. each removal of the reactor vessel head.
CALLAWAY PLANT 3.1-18 Amendment No. 133
PHYSICS TESTS Exceptions - MODE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PHYSICS TESTS Exceptions - MODE 2 LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of LCO 3.1.3, "Moderator Temperature Coefficient (MTC)";
LCO 3.1.4, "Rod Group Alignment Limits";
LCO 3.1.5, "Shutdown Bank Insertion Limits";
LCO 3.1.6, "Control Bank Insertion Limits"; and LCO 3.4.2, "RCS Minimum Temperature for Criticality" may be suspended, and the number of required channels for LCO 3.3.1, "RTS Instrumentation," Functions 2, 3, 6, and 18.e, may be reduced to 3 required channels provided:
- a. RCS lowest operating loop average temperature is 2541 OF;
- c. THERMAL POWER is
- 5% RTP.
APPLICABILITY: MODE 2 during PHYSICS TESTS.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A SDM not within limit. A.1 Initiate boration to 15 minutes restore SDM to within limit.
AND A.2 Suspend PHYSICS 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> TESTS exceptions.
B. THERMAL POWER not B.1 Open reactor trip Immediately within limit. breakers.
(continued)
CALLAWAY PLANT 3.1-19 Amendment No. 154 APR 21 2003
PHYSICS TESTS Exceptions - MODE 2 3.1.8 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. RCS lowest operating loop C.1 Restore RCS lowest 15 minutes average temperature not operating loop average within limit. temperature to within limit.
D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATIONAL TEST on Prior to initiation of power range and intermediate range channels per SR PHYSICS TESTS 3.3.1.7, SR 3.3.1.8, and Table 3.3.1-1.
SR 3.1.8.2 Verify the RCS lowest operating loop average In accordance temperature is ~ 541°F. with the Surveillance Frequency Control Program SR 3.1.8.3 Verify THERMAL POWER is :s; 5% RTP. In accordance with the Surveillance Frequency Control Program (contInued)
CALLAWAY PLANT 3.1-20 Amendment No. 202
PHYSICS TESTS Exceptions - MODE 2 3.1.8 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.1.8.4 Verify SDM is within limits provided in the COLR. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-21 Amendment No. 202
RCS Boron Limitations <: 500°F 3.1.9 3.1 REACTIVITY CONTROL SYSTEMS 3.1.9 RCS Boron Limitations <: 500 0 F LCO 3.1.9 The boron concentration of the Reactor Coolant System (RCS) shall be greater than the all rods out (ARO) critical boron concentration.
APPLICABILITY: MODE 2 with keff <: 1.0 with any RCS cold leg temperature <: 500°F and with Rod Control System capable of rod withdrawal.
MODE 3 with any RCS cold leg temperature < 500°F and with Rod Control System capable of rod withdrawal.
MODES 4 and 5 with Rod Control System capable of rod withdrawal.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A RCS boron concentration A.1 Initiate boration to Immediately not within limit. restore RCS boron concentration to within limit.
OR A2 Initiate action to place Immediately the Rod Control System in a condition incapable of rod withdrawal.
OR A3 ------ NOTE -------
Not applicable in MODES 4 and 5.
Initiate action to increase Immediately all RCS cold leg temperatures to ~ 500°F.
CALLAWAY PLANT 3.1-22 Amendment No. 202 Corrected
RCS Boron Limitations < 500°F 3.1.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Verify RCS boron concentration is greater than the In accordance ARO critical boron concentration. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.1-23 Amendment No. 202
FQ(Z) (F0 Methodology) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (F,(Z)) (F. Methodology)
LCO 3.2.1 Fa(Z), as approximated by Fc(Z) and 1710(Z), shall be within the limits specified in the COLR.
APPLICABILITY: MODE 1.
ACTIONS CONDITION REQUIRED ACTION TIME A. F&(Z) not within limit. A.1 Reduce THERMAL 15 minutes after POWER 2 1% RTP for each Fc(Z) each 1% Fca(Z) exceeds determination limit.
AND A.2 Reduce Power Range 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each Neutron Flux - High trip Fc(Z) determination setpoints 2 1% for each 1% Fc(Z) exceeds limit.
AND A.3 Reduce Overpower AT 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each trip setpoints 2 1% for Fc(Z) determination each 1% Fa(Z) exceeds limit.
AND A.4 Perform SR 3.2.1.1. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)
CALLAWAY PLANT 3.2-1 Amendment No. 133
Fa(Z) (Fo Methodology) 3.2.1 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Fwa(Z) not within limits. B.1 Reduce AFD limits 2 1% 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for each 1% Fc(Z) exceeds limit.
C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
CALLAWAY PLANT 3.2-2 Amendment No. 133
Fa(Z) (Fa Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS
NOT E ----------------------------------------------------------
During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained.
SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify F8(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium conditions after exceeding, by
~ 10% RTP, the THERMAL POWER at which F8(Z) was last verified In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-3 Amendment No. 202
FQ(Z) (FQ Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.2.1.2 NUll------------------------------
If Fc(Z) measurements indicate z FZ)]
maximum over has increased since the previous evaluation of F&(Z)
- a. Increase F '(Z) by the appropriate factor specified in the COLR and reverify Fw(Z) is within limits; or
- b. Repeat SR 3.2.1.2 once per 7 EFPD until two successive power distribution measurements I indicate
[FF(Z)]
K(Z) J maximum over z has not increased.
Verify Fw(Z) is within limit Once after each refueling prior to THERMAL POWER exceeding 75%
RTP AND (continued)
CALLAWAY PLANT 3.2-4 Amendment No. 182
Fa(Z) (Fa Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued) Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium conditions after exceeding, by
~ 10% RTP, the THERMAL POWER at which was last verified In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-5 Amendment 202
FNA2H 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FIH)
LCO 3.2.2 F&H shall be within the limits specified in the COLR.
APPLICABILITY: MODE 1.
ACTIONS CONDITION REQUIRED ACTION TIME A. NOTE E A.1.1 Restore F&H to within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Required Actions A.2 limit.
and A.3 must be completed whenever Condition A is OR entered.
A.1.2.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> POWER to < 50% RTP.
F&H not within limit.
AND A.1.2.2 Reduce Power Range 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Neutron Flux - High trip setpoints to s 55% RTP.
AND A.2 Perform SR 3.2.2.1. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND (continued)
CALLAWAY PLANT 3.2-6 Amendment No. 133
FNAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION TIME A. (continued) A.3 - NOTE THERMAL POWER does not have to be reduced to comply with this Required Action.
Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER reaching 2 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
CALLAWAY PLANT 3.2-7 Amendment No. 133
SURVEILLANCE REQUIREMENTS
NOT E ----------------------------------------------------------.
During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained.
SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify F t1NH is within limits specified in the COLR. Once after each refueling prior to THERMAL POWER exceeding 75% RTP In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-8 Amendment No. 202
AFD (RAOC Methodology) 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology)
LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.
NOT E -------------------------------------------
The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.
APPLICABILITY: MODE 1 with THERMAL POWER ~ 50% RTP.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore In accordance channel. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-9 Amendment No. 202
QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)
LCO 3.2.4 The QPTR shall be s 1.02.
APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. QPTR not within limit. A.1 Reduce THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after each POWER > 3% from RTP QPTR for each 1% of QPTR determination
> 1.00.
AND A.2 Determine QPTR. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND A.3 Perform SR 3.2.1.1, 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after SR 3.2.1.2 and achieving SR 3.2.2.1. equilibrium conditions from a THERMAL POWER reduction per Required Action A.1 AND Once per 7 days thereafter AND (continued)
CALLAWAY PLANT 3.2-1 0 Amendment No. 133
QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION
_ __ __ _ _TIM
_ E A. (continued) A.4 Reevaluate safety Prior to increasing analyses and confirm THERMAL results remain valid for POWER above the duration of operation limit of Required under this condition. Action A.1 AND A.5 ___NOTES
- 1. Perform Required Action A.5 only after Required Action A.4 is completed.
- 2. Required Action A.6 shall be completed whenever Required Action A.5 is performed.
Normalize excore Prior to increasing detectors to restore THERMAL QPTR to within limit. POWER above the limit of Required Action A.1 AND (continued)
CALLAWAY PLANT 3.2-1 1 Amendment No. 133
QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. (continued) A.6 NOTE Perform Required Action A.6 only after Required Action A.5 is completed.
Perform SR 3.2.1.1, 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after SR 3.2.1.2 and achieving SR 3.2.2.1. equilibrium conditions not to exceed 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to s 50% RTP.
Time not met.
CALLAWAY PLANT 3.2-1 2 Amendment No. 133
QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 --------------------------------- NOTE ----------------------------
- 1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER s 75% RTP, the remaining three power range channels can be used for calculating QPTR.
- 2. SR 3.2.4.2 may be performed in lieu of this Surveillance.
Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control Program SR 3.2.4.2 --------------------------------- NOTE ----------------------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER
> 75% RTP.
Verify QPTR is within limit using power distribution In accordance measurement information. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.2-13 Amendment No. 202
RTS Instrumentation 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1 -1 shall be OPERABLE.
APPLICABILITY: According to Table 3.3.1-1.
ACTIONS I.Erf%1 IMLJ I r-Separate Condition entry is allowed for each Function.
CONDITION REQUIRED ACTION COMPLETION A. One or more Functions A.1 Enter the Condition Immediately with one or more required referenced in channels or trains Table 3.3.1-1 for the inoperable. channel(s) or train(s).
B. One Manual Reactor Trip B.1 Restore channel to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> channel inoperable. OPERABLE status.
OR B.2 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> (continued)
CALLAWAY PLANT 3.3-1, Amendment No. 133
RTS Instrumentation 3.3.1 ACTIONS (continued)
REQUIRED ACTION COMPLETION TIME CONDITION C. One channel or train C.1 Restore channel or train 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> Inoperable. to OPERABLE status. I OR C.2.1 Initiate action to fully 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> insert all rods.
AND C.2.2 Place the Rod Control 49 hours5.671296e-4 days <br />0.0136 hours <br />8.101852e-5 weeks <br />1.86445e-5 months <br /> System in a condition incapable of rod withdrawal.
(continued)
CALLAWAY PLANT 3.3-2 Amendment No. 164
k RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION D. One Power Range Neutron -- NOTE Flux - High channel The inoperable channel may be inoperable. bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing and setpoint adjustment of other channels.
D.1.1 ------- NOTE Only required when the Power Range Neutron Flux input to QPTR is inoperable.
Perform SR 3.2.4.2. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from discovery of THERMAL POWER >75%
RTP AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND D.1.2 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR D.2 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> (continued)
CALLAWAY PLANT 3.3-3 Amendment No. 165
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION E. One channel inoperable. NOTE - ---
The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for I surveillance testing of other channels.
E.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> I OR E.2 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> I F. One Intermediate Range F.1 Reduce THERMAL 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Neutron Flux channel POWER to < P-6.
OR F.2 Increase THERMAL 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> POWER to > P-10.
(continued)
CALLAWAY PLANT 3.3-4 Amendment No. 165
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIREDACTION TIME G. Two Intermediate Range Gi NOTE Neutron Flux channels Limited boron inoperable. concentration changes associated with RCS inventory control or limited plant temperature changes are allowed.
Suspend operations Immediately involving positive reactivity additions.
AND G.2 Reduce THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> POWER to < P-6.
H. Not used.
- 1. One Source Range 1.1 ---- NOTE-Neutron Flux channel Limited boron inoperable. concentration changes associated with RCS inventory control or limited plant temperature changes are allowed.
Suspend operations Immediately involving positive reactivity additions.
J. Two Source Range J.1 Open reactor trip Immediately Neutron Flux channels breakers (RTBs).
(continued)
CALLAWAY PLANT 3.3-5 Amendment No. 149
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION K. One Source Range K.A Restore channel to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> Neutron Flux channel OPERABLE status.
OR K.2.1 Initiate action to fully 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> insert all rods.
AND K.2.2 Place the Rod Control 49 hours5.671296e-4 days <br />0.0136 hours <br />8.101852e-5 weeks <br />1.86445e-5 months <br /> System in a condition incapable of rod withdrawal.
L. Not used.
M. One channel inoperable. NOTE The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for I surveillance testing of other channels.
M.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> I OR M.2 Reduce THERMAL 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> I POWER to < P-7.
(continued)
CALLAWAY PLANT 3.3-6 Amendment No. 165
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION TIME N. Not used.
- 0. One Low Fluid Oil Pressure NOTE Turbine Trip channel The inoperable channel may be inoperable. bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
0.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR 0.2 Reduce THERMAL 76 hours8.796296e-4 days <br />0.0211 hours <br />1.256614e-4 weeks <br />2.8918e-5 months <br /> POWER to < P-9.
P. One or more Turbine Stop RI Place channel(s) in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Valve Closure Turbine Trip channel(s) inoperable. OR P.2 Reduce THERMAL 76 hours8.796296e-4 days <br />0.0211 hours <br />1.256614e-4 weeks <br />2.8918e-5 months <br /> POWER to < P-9.
(continued)
CALLAWAY PLANT 3.3-7 Amendment No. 165
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION ACTIONCOMPLETION TIME Q One train inoperable. ----------------- NOTE ----------
One train may be bypassed for up to
.4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing provided the other train is OPERABLE.
Q.1 Restore train to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status..
OR Q.2 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> R One RTB train inoperable. -------------- NOTE ----------
One train may be bypassed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing provided the other train is OPERABLE.
R.1 Restore train to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
OR R.2 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> S. One or more required S.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channel(s) inoperable, required state for existing unit conditions.
OR S.2 Be in MODE 3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> (continued)
CALLAWAY PLANT 3.3-8 Amendment No. 174
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME T. One or more required T.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channel(s) inoperable, required state for existing unit conditions.
OR T.2 Be in MODE 2. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> U. One trip mechanism A.1 Restore inoperable trip 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable for one RTB. mechanism to OPERABLE status.
OR U.2 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> (continued)
CALLAWAY PLANT 3.3-9 Amendment No. 174
RTS Instrumentation 3.3.1 ACTIONS (continued)
CONDITION I REQUIRED ACTION T COMPLETION TIME V. One channel inoperable. - ------------------- NOTE ----------
The inoperable channelmay be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
V.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR V.2.1 Be in MODE 2 with 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> keff < 1.0.
AND V.2.2.1 Initiate action to fully 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> insert all rods.
AND V.2.2.2 Initiate action to place 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> the Rod Control System in a condition incapable of rod withdrawal.
OR V.2.3 Initiate action to borate 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> the RCS to greater than the all rods out (ARO) critical boron concentration.
+ +
W Not used.
(continued)
CALLAWAY PLANT 3.3-10 Amendment No. 174
RTS Instrumentation 3.3.1 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME X One or more Containment X.1 Place channel(s) in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Pressure - Environmental Allowance Modifier OR channel(s) inoperable.
X.2 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> Y. One channel inoperable ---- NOTE ----------
The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
Y1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> I
Z Required Action and Z.1.1 Initiate action to fully Immediately associated Completion insert all rods.
Time of Condition Y not met. AND OR Z.1.2 Initiate action to place Immediately the Rod Control System Two or more channels in a condition incapable inoperable, of rod withdrawal.
OR Z.2 Initiate action to borate Immediately the RCS to greater than the all rods out (ARO) critical boron concentration.
CALLAWAY PLANT 3.3-11 Amendment No. 174
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS
NOTE ----------------------------------------------------------
Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.
SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 --------------------------------- NOTE ---------------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is ~ 15% RTP.
Compare results of calorimetric heat balance In accordance calculation to power range channel output. Adjust with the power range channel output if calorimetric heat Surveillance balance calculation results exceed power range Frequency channel output by more than +2% RTP. Control Program SR 3.3.1.3 --------------------------------- NOTE -------.-------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is ~ 50% RTP.
Compare results of the incore power distribution In accordance measurements to Nuclear Instrumentation System with the (NIS) AFD. Adjust NIS channel if absolute difference Surveillance is ~2%. Frequency Control Program (continued)
CALLAWAY PLANT 3.3-12 Amendment No. 202
RTS Instrumentation 3.3.1 SURVEILLANCE FREQUENCY SR 3.3.1.4 --------------------------------- NOTE ---------------------------
This Surveillance must be performed on the reactor trip bypass breaker for the local manual shunt trip only prior to placing the bypass breaker in service.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 --------------------------------- NOTE ---------------------------
Not required to be performed until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after achieving equilibrium conditions with THERMAL POWER ~ 75 % RTP.
Calibrate excore channels to agree with incore power In accordance distribution measurements. with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.3-13 Amendment No. 202
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued)
SURVEILLANCE FREQUENCY SR 3.3.1.7 --------------------------------- NOTE ---------------------------
- 1. Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after entry into MODE 3.
- 2. Source range instrumentation shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.
Perform COT. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-14 Amendment No. 202
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.8 --------------------------------- NOTE ---------------------------
This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.
Perform COT. ------- NOTE -------
Only required when not performed within the frequency specified in the Surveillance Frequency Control Program Prior to reactor startup 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reducing power below P-10 for power and intermediate instrumentation Four hours after reducing power below P-6 for source range instrumentation CALLAWAY PLANT 3.3-15 Amendment No. 202
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.8 (continued)
In accordance with the Surveillance Frequency Control Program SR 3.3.1.9 --------------------------------- NOTE --------------------------
Verification of setpoint is not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 --------------------------------- NOTE ---------------------------
This Surveillance shall include verification that the time constants are adjusted to the prescribed values.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (contlnueo)
CALLAWAY PLANT 3.3-16 Amendment 202
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.11 --------------------------------- NOTE ---------------------------
- 1. Neutron detectors are excluded from CHANNEL CALIBRATION.
- 2. This Surveillance shall include verification that the time constants are adjusted to the prescribed values.
- 3. Power and intermediate range detector plateau voltage verification is not required to be performed until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after achieving equilibrium conditions with THERMAL POWER 2 95% RTP.
Perform CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Not used.
SR 3.3.1.13 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 --------------------------------- NOTE ---------------------------
Verification of setpoint is not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.3-17 Amendment No. 202
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE I I=REQUENCY SR 3.3.1.15 --------------------------------- NOTE ---------------------------
Verification of setpoint is not required.
Perform TADOT. Prior to exceeding the P 9 interlock whenever the unit has been in MODE 3, if not performed in the previous 31 days SR 3.3.1.16 --------------------------------- NOTE ---------------------------
Neutron detectors are excluded from response time testing.
Verify RTS RESPONSE TIMES are within limits. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-18 Amendment No. 202
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (PAGE 1 OF 8)
Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 1. Manual Reactor 1,2 2 B SP 3 3.1 1t1 NA Trip 3(b), 4(b), Sib) 2 C SF': 3.3.1 ~4 NA
- 2. Power Range Neutron Flux
- b. Low 1(c),2(f) 4 V SR 3.3.1.1 28.3% RTP SR 3.3.1.8 SR 3.3.1 11 SR3.3.116 2(h),3(i) 4 Y,Z SR3.3.1.1 :::;28.3% RTP SR 331.8 SR 3.3.1!
SR 33.1.1
- 3. Power Range 1,2 4 E SR :33.1.7 6.3 % RTP Neutron Flux SR 3 3.1 1 with time Rate - High SH 3.31.16 constant Positive Rate 2 sec
- 4. Intermediate 1(e),2(d) 2 F, G SR 3 3.1.1 :::; 35.3% RTP Range Neutron SR 3318 Flux SF{ 3.31.11 (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.
(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.
(c) Below the P-l0 (Power Range Neutron Flux) interlock.
(d) Above the P-6 (Intermediate Range Neutron Flux) interlock.
(f) With kef! ~ 1.0.
(h) With kef! < 1.0, and all RCS cold leg temperatures ~ 500°F, and RCS boron concentration s; the ARO critical boron concentration, and Rod Control System capable of rod withdrawal or one or more rods not fully inserted.
(i) With all RCS cold leg temperatures?: 500°F, and RCS boron concentration s; the ARO critical boron concentration, and Rod Control System capable of rod withdrawal or one or more rods not fully inserted CALLAWAY PLANT 3,3-19 Amendment No. 202 I
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (PAGE 2 OF 8)
Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 5. Source Range 2(e) 2 I, J :s: 1.6 E5 cps Neutron Flux 3. 4 . s 2 J, K :s: 1.6 E5 cps
- 6. Overtemperature 1,2 4 E Sf? 3<3. i 1 Refer to Note 1 t.T (at the end of this Table) i 7 1 10
- 7. Overpower L'.T 1,2 4 E Refer to Note 2
~~ 7 (at the end of this Table) 1 1C
- 8. Pressurizer Pressure
- a. Low 1(9) 4 M .;
'l ;:, 1874 psig
- b. High 1,2 4 E 1 1 :s: 2393 psig 1 r (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.
(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.
(e) Below the P-6 (Intermediate Range Neutron Flux) interlock.
(g) Above the P-7 (Low Power Reactor Trips Block) interlock.
CALLAWAY PLANT 3.3-20 Amendment No. 210
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (PAGE 3 OF 8)
Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 10. Reactor Coolant 3 per loop M SR 3.3.1.1 ~ 88.8% of Flow - Low SR 3.3.17 indicated loop SR ~U.1.10 flow SR 3.3.116
- 11. Not Used
- 12. Undervoltage 2/bus M SR 3.3.1.9 ~ 10105 Vac RCPs SR 3.3.1.10 SR 3.3.116
- 13. Underfrequency 2/bus M SR 3.3.1.9 ~ 57.1 Hz RCPs SR 3.3.1 10 SR 3.3.1 16
- 14. Steam Generator (SG) Water Level Low-Low(l)
- a. Steam 1,2 4 per SG E SR 3 3.1 1 ~ 20.6% (q) of Generator SR 3.3.1.7 Narrow Range Water Level SR 3.3.1.10 Instrument Low-Low SR 3.3.1.16 Span (Adverse Containment Environment)
(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.
(g) Above the P-7 (Low Power Reactor Trips Block) interlock.
(I) The applicable MODES for these channels in Table 3.3.2-1 are more restrictive.
(m) Not used.
(q) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases CALLAWAY PLANT 3.3-21 Amendment No. 202 I
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (PAGE 4 OF 8)
Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 14. Steam Generator (SG) Water Level Low-Low(l)
- b. Steam 4 per SG E SR3.3.1.1 ~ 16.6% (q) of Generator SR 3.3.17 Narrow Range Water Level SR 3.3.1 10 Instrument Low-Low SR 3.3.1 16 Span (Normal Containment Environment)
- c. Not used.
- d. Containment 1,2 4 x SR:U.11 ~ 2.0 psig Pressure SR :U.1.7 Environmental SR 3.3.1.10 Allowance SR 3.3.1 1G Modifier
- 15. Not Used (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.
(I) The applicable MODES for these channels in Table 3.3.2-1 are more restrictive.
(n) Not used.
(0) Not used.
(p) Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.
(q) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases CALLAWAY PLANT 3.3-22 Amendment No. 202 I
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (PAGE 5 OF 8)
Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 16. Turbine Trip
- a. Low Fluid 3 o SR 3.:1.1.10 539.42 psig Oil Pressure SR 33.1.15
- b. Turbine 4 P SR3.3.1.10 ~ 1% open Stop Valve sr~ :331 15 Closure
- 17. Safety Injection 1,2 2 trains Q SR 3.3.1 14 NA (SI) Input from Engineered Safety Feature Actuation System (ESFAS)
- 18. Reactor Trip System Interlocks
- b. Low Power 1 per train T SR 33.1.5 NA Reactor Trips Block, P-7
- d. Power 4 T SR 3.3.1.11 <:; 53,3% RTP Range SR:U.113 Neutron Flux, P-9 (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints, (e) Below the P-6 (Intermediate Range Neutron Flux) interlock.
U) Above the P-9 (Power Range Neutron Flux) interlock.
CALLAWAY PLANT 3.3-23 Amendment No. 202 I
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (PAGE 6 OF 8)
Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 18. Reactor Trip System Interlocks
- f. Turbine 2 T SR :)3.1.10 $12.4%
Impulse SR 3.3.1.13 turbine power Pressure, P-13
- 19. Reactor Trip 1,2 2 trains R SR 3.3.1.4 NA Breakers (RTBs)(k) 3(b), 4(b), 5(b) 2 trains C SR 331.4 NA
- 20. Reactor Trip 1,2 1 each per U SR :331.4 NA Breaker RTB Undervoltage and Shunt Trip 3(b), 4(b), 5(b) 1 each per C SR :J.3.1.4 NA Mechanisms(k) RTB
- 21. Automatic Trip 1,2 2 trains Q SR 3.3.15 NA Logic 3(b), 4(b), 5(b) 2 trains C SR 3.3.1.5 NA (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.
(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.
(k) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.
CALLAWAY PLANT 3.3-24 Amendment No. 202 I
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (page 7 of8)
Reactor Trip System Instrumentation Note 1: Overtemperature ~ T The Overtemperature ~T Function Allowable Value shall not exceed the following setpoint by more than 1.23% of ~ T span (1.85% RTP).
flT(1+'1 )( 1 -1~flTo{K1-K2[(1+'4S)T S
1 rJ+K 3 (p-P') f 1 (fll)}
(1 + '2S) 1 + '3SJ (1 + '5S) 1 + '6S Where: ~T is measured RCS ~ T, of.
~ To is the indicated t. T at RTP, of.
s is the Laplace transform operator, sec* 1.
T is the measured RCS average temperature, OF.
T' is the nominal Tavg at RTP, $ oOF.
P is the measured pressurizer pressure, psig.
P' is the nominal RCS operating pressure = 0 psig.
K1 = 0 K2 = °/oF K3 */psig
'1 ~
- sec '2 $ 0 sec '3
- sec
'4 ~
- sec '5 $ 0 sec '6
- sec
- {*% + (q! - qb)} when qt - qb <: * %RTP 0% ofRTP when' %RTP $ ql qb $ * %RTP
- {(qt - qb)- *} when q! - qb > * %RTP where qt and qb are percent RTP in the upper and lower halves of the core, respectively, and ql + qb is the total THERMAL POWER in percent RTP.
The values denoted with' are specified in the COLR.
CALLAWAY PLANT Amendment 202 I
RTS Instrumentation 3.3.1 TABLE 3.3.1-1 (page 8 of 8)
Reactor Trip System Instrumentation Note 2: Overpower t,T The Overpower t, T Function Allowable Value shall not exceed the following setpoint by more than 1.21 % of t, T span (1.82% RTP).
Where: t, T is measured RCS t, T, oF.
t,To is the indicated t, T at RTP, oF.
s is the Laplace transform operator, sec* 1 .
T is the measured RCS average temperature,°F.
T" is the nominal Tavg at RTP, S 'oF.
Ks =',OF for increasing Tavg K6 =',OF when T> T"
',OF for decreasing Tavg ',OF when T s T"
'1 ;:>: , sec '2 s' sec '3 =' sec
'6 =' sec '7;:>: , sec The values denoted with' are specified in the COLR.
CALLAWAY PLANT 3.3-26 Amendment 202 I
ESFAS Instrumentation 3.3.2 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.
APPLICABILITY: According to Table 3.3.2-1.
ACTIONS
NOTE ------------------------------------------------------.---
Separate Condition entry is allowed for each Function.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 Enter the Condition Immediately one or more required referenced in channels or trains Table 3.3.2-1 for the inoperable. channel(s) or train(s).
B. One channel or train B.1 Restore channel or train 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable. to OPERABLE status.
OR B.2.1 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> 81:iD.
B.2.2 Be in MODE 5. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> (continued)
CALLAWAY PLANT 3.3-27 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. One train inoperable. ------------------- NOTE ------------------
One train may be bypassed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing provided the other train is OPERABLE.
C.1 ------------ NOTE ----------
Only required if Function 3.a.(2) is inoperable.
Place and maintain Immediately containment purge supply and exhaust valves in closed position.
AND C.2 Restore train to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
OR C.3.1 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> AND C.3.2 Be in MODE 5. 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br /> l continued}
CALLAWAY PLANT 3.3-28 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME D. One channel inoperable. ------------------- NOTE ------------------
The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
D.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR D.2.1 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> AND D.2.2 Be in MODE 4. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> E. One Containment Pressure ------------------- NOTE ------------------
channel inoperable. One additional channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing.
E.1 Place channel in bypass. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR E.2.1 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> AND E.2.2 Be in MODE 4. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> (contln ued )
CALLAWAY PLANT 3.3-29 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME F. One channel or train F.1 Restore channel or train 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable. to OPERABLE status.
QB F.2.1 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> AND F.2.2 Be in MODE 4. 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br /> G One train inoperable. ------------------- NOTE ------------------
One train may be bypassed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing provided the other train is OPERABLE.
G.1 Restore train to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
OR G.2.1 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> AND G.2.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> H. One or more trains ------------------- NOTE ------------------
inoperable. One train may be bypassed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing provided the other train is OPERABLE.
H.1 Declare associated Immediately Pressurizer PORV(s) inoperable.
(contlnueo)
CALLAWAY PLANT Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME I. One channel inoperable. ------------------ NOTE ------------------
The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
1.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR 1.2 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> J. One channel inoperable. ------------------ NOTE ------------------
The inoperable channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing of other channels.
J.1 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR J.2 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> (ContinUed)
CALLAWAY PLANT 3.3-31 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME K. One channel inoperable. ------------------- NOTE ------------------
An inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
K.1 Restore channel to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
OR K.2.1 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> AND K.2.2 Be in MODE 5. 108 hours0.00125 days <br />0.03 hours <br />1.785714e-4 weeks <br />4.1094e-5 months <br /> L. One or more required L.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channel{s) inoperable. required state for existing unit condition.
OR L.2.1 Be in MODE 3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> AND L.2.2 Be in MODE 4. 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> (continued)
CALLAWAY PLANT 3.3-32 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME M. Two channels inoperable. M.1 Place channels in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND OR AFW actuation on Trip of all M.2 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> Main Feedwater Pumps maintained from one actuation train.
N. One or more Containment N.1 Place channel(s) in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Pressure - Environmental Allowance Modifier OR channel(s) inoperable.
N.2.1 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> AND N.2.2 Be in MODE 4. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> O. One channel inoperable. 0.1 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND 0.2 Restore channel to During OPERABLE status. performance of the next required COT (continUed)
CALLAWAY PLANT 3.3-33 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME P. One or more channel(s) P.1 Declare associated Immediately inoperable. auxiliary feedwater pump(s) inoperable.
AND P.2 Declare associated Immediately steam generator blowdown and sample line isolation valve(s) inoperable.
Q One train inoperable. ------------------- NOTE ------------------
One train may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing provided the other train is OPERABLE.
Q.1 Restore train to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
OR Q.2.1 Be in MODE 3. 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> AND Q.2.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)
CALLAWAY PLANT 3.3-34 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME R. One or both train(s) R.1 Restore train(s) to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable. OPERABLE status.
OR R.2.1 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> AND R.2.2 Be in MODE 4. 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br /> S. One train inoperable ------------------- NOTE ------------------
One train may be bypassed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing provided the other train is OPERABLE.
S.1 Restore train to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> OPERABLE status.
OR S.2.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND S.2.2 Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> CALLAWAY PLANT 3.3-35 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS
NOT E ----------------------------------------------------------
Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.
SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.3 --------------------------------- NOTE ---------------------------
The continuity check may be excluded from the BOP ESFAS test.
Perform ACTUATION LOGIC TEST. I n accordance with the Surveillance Frequency Control Program SR 3.3.2.4 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.3-36 Amendment No. 202
ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.2.5 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.6 --------------------------------- NOT E ---------------------------
Not applicable to slave relays K602, K620, K622, K624, K630, K740, K741 , and K750.
Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 --------------------------------- NOTE ---------------------------
Verification of relay setpoints not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.8 --------------------------------- NOTE ---------------------------
Verification of setpoint not required for manual initiation functions.
Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.3-37 Amendment No. 202
ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)
SU RVEI LLANCE FREQUENCY SR 3.3.2.9 --------------------------------- NOT E ---------------------------
This Surveillance shall include verification that the time constants are adjusted to the prescribed values.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.10 --------------------------------- NOTE ---------------------------
Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after SG pressure is
~ 900 psig.
Verify ESF RESPONSE TIMES are within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.2.11 --------------------------------- NOTE ---------------------------
Verification of setpoint not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.12 Perform COT. In accordance with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.3-38 Amendment No. 202
ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.2.13 --------------------------------- NOTE ---------------------------
Only applicable to slave relays K602, K622, K624 ,
K630, K740, and K741.
Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program Prior to entering MODE 4 when in MODE 5 or 6
> 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, if not performed within the previous 92 days SR 3.3.2.14 --------------------------------- NOTE ---------------------------
Only applicable to slave relays K620 and K750.
Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program Prior to entering MODE 3 when in MODE 5 or 6
> 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, if not performed within the previous 92 days CALLAWAY PLANT 3.3-39 Amendment No. 202
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 1. Safety Injection a, Manual 1,2,3,4 2 B SR 3,3.2 8 NA Initiation
- b. Automatic 1,2,3,4 2 trains C SR 3.3,2.2 NA Actuation Sf~ 3.3,2.4 Logic and SR 3.3,2,(i Actuation SR 3,3,2,1]
Relays (SSPS)
- c. Containment 1,2,3 3 D SR :\3,2.1 ~ 4,5 psig Pressure SR ~1325 High 1 SR :\.32.9 SR 33.2.10 d, Pressu rizer 1,2,3(b) 4 D SR 3321 2: 1834 psig Pressure SR 3.3.2,5 Low SR 3,3.2,9 SR 3.3,2,10 e, Steam Line 1,2,3(b) 3 per steam D SR 3,32.1 2: 610 pSig(C)(S)
Pressure line SR 3.3.2.5 Low SR 3.3.2,9 SR 3.3,2,10
- a. Manual 1,2,3,4 2 per train, B SR 3,3,2 8 NA Initiation 2 trains
- b. Automatic 1,2,3,4 2 trains C SR 3,3,2 2 NA Actuation SR :U,2.4 Logic and SR 3.3.2.0 Actuation Relays (SSPS)
(a) The Allowable Value defines the limiting safety system setting except for Functions 1 ,e, 4,e,(1), 5,c, 5,e,(1), 5.e.(2),
6.d.(1), and 6.d,(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints, (b) Above the P-11 (Pressurizer Pressure) interlock and below P-11 unless the Function is blocked.
(c) Time constants used in the lead/lag controller are '1 2: 50 seconds and '2 s 5 seconds.
(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Set point; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.
CALLAWAY PLANT 3.3-40 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 2. Containment Spray c, Containment 1.2.3 4 E SR :>3.2.1 s 28.3 psig Pressure SR 3,3.2.5 High - 3 SR 3.3.2,9 SR 3.3,2,10
- 3. Containment Isolation
- a. Phase A Isolation (1) Manual 1.2.3,4 2 B SR 3,3.2.8 NA Initiation (2) Automatic 1.2.3,4 2 trains C SR 3.3,2.2 NA Actuation SR 3.3.2.4 Logic and SR 3 3.2.6 Actuation SR 3.3.2.13 Relays (SSPS)
(3) Safety Refer to Function 1 (Safety Injection) for all initiation functions and requirements.
Injection
- b. Phase B Isolation (1) Manual 1,2,3,4 2 per train, B SR 3,3.2 8 NA Initiation 2 trains (2) Automatic 1,2,3,4 2 trains C SR 3,3,2.2 NA Actuation SR 3,3,24 Logic and SR 3,3,2.6 Actuation Relays (SSPS)
(3) Contain- 1,2,3 4 E SR 3.3.2.1 s 28.3 psig ment SR 3.3.2.5 Pressure SR 3.3.2.9 High - 3 SR3.32.10 (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1). 5.c, 5.e.(1), 5.e,(2},
6,d,(1). and 6.d,(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
CALLAWAY PLANT 3.3-41 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 4. Steam Line Isolation
- a. Manual Initiation 1,2(i)(k), 3(i)(k) 2 F SR :U.2.R NA
- b. Automatic 1,2(i)(k), 3(i)(k) 2 trains G SR 3.3.2.2 NA Actuation Logic SF{ 3.:3.2 4 and Actuation SF< :U.2.6 Relays (SSPS)
- c. Automatic 1, 2(k),3(k) 2 trains(o) S SR :U23 NA Actuation Logic and Actuation Relays (MSFIS)
- d. Containment 1,2(i)(k), 3(i)(k) 3 D SR ~'l.3.2.1 ~ 18.3 psig Pressure - High 2 SR 3.3.2.5 SR 3.3.2.D SR 3 ;3210 (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2).
6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(i) Except when:
- 1. All MSIVBVs are:
1.a Closed and de-activated, or 1.b Closed and isolated by a closed manual valve, or 1.c Isolated by two closed manual valves.
AND
- 2. All MSLPDIVs are:
2.a Closed and de-activated, or 2.b Closed and isolated by a closed manual valve, or 2.c Isolated by two closed manual valves.
(k) Except when all MSIVs are closed and de-activated.
(0) Each train requires a minimum of two programmable logic controllers to be OPERABLE.
CALLAWAY PLANT 3.3-42 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 4. Steam Une Isolation
- e. Steam Une Pressure (1) Low 1,2 (i)(k), 3(b)(i)(k) 3 per steam D SR:3 321 ~ 610 pSig(C)(S) line SR 33.25 SR 33.29 SR 332.10 (2) Negative 3(g)(i)(k) 3 per steam D SR 3.321 5124 psi(h)
Rate - High line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (a) The Allowable Value defines the limiting safety system setting except for Functions 1 ,e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),
6.d,(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11 unless the Function is blocked.
(c) Time constants used in the leadllag controller are '1 ~ 50 seconds and '2 5 seconds.
(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-11 when safety injection on low steam line pressure is not blocked.
(h) Time constant utilized in the ratellag controller is ~ 50 seconds.
(i) Except when:
- 1. All MSIVBVs are:
1.a Closed and de-activated, or 1.b Closed and isolated by a closed manual valve, or 1,c Isolated by two closed manual valves.
AND
- 2. All MSLPDIVs are:
2.a Closed and de-activated, or 2.b Closed and isolated by a closed manual valve, or 2.c Isolated by two closed manual valves.
(k) Except when all MSIVs are closed and de-activated.
(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.
CALLAWAY PLANT 3.3-43 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 5. Turbine Trip and Feedwater Isolation
- a. Automatic 1(j) ,2 (j) ,3 (j) 2 trains G SR :)32 2 NA Actuation Logic SR :13.2.4 and Actuation SR :U.2,6 Relays (SSPS) SR 3.3.2.14
- b. Automatic 2 trains(O) S SR 3.3.2.3 NA Actuation Logic and Actuation Relays (MSFIS) c, SG Water Level 4 per SG SR 3.3.2.1 :; 91.4%(s) of High High (P-14) SR 3.3.2,5 Narrow Range SR 3,3.2,9 Instrument SR 3.32.10 Span
- d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements. The Applicability exceptions of Footnote (j) also apply to Function 5.d.
(a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(I), 5.c, 5.e.(1). 5.e.(2),
6.d.(I), and 6.d.(2} (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
Except when:
1 All MFIVs are closed and de-activated:
AND
- 2. All MFRVs are:
2.a Closed and de-activated, or 2.b Closed and isolated by a closed manual valve; AND
- 3. All MFRVBVs are:
3.a Closed and de-activated, or 3.b Closed and isolated by a closed manual valve. or 3.c Isolated by two closed manual valves.
(I) Except when all MFIVs are closed and de-activated.
(o) Each train requires a minimum of two programmable logic controllers to be OPERABLE.
(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise.
the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.
CALLAWAY PLANT 3.3-44 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 5. Turbine Trip and Feedwater Isolation
- e. Steam Generator Water Level Low-Low(q)
(1) Steam 1m, 2m, 3m 4 per SG D SR:U.2.1 Z 20.6%(5) of Generator SR 3.3.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Adverse Containment Environment)
(2) Steam 1m(r), 2(j)(r), 3(j)(r) 4 per SG D SR 3.3.2.1 z 16.6%(5) of Generator SR :33.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Normal Containment Environment)
(a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1}, 5.c, 5.e.(1}, 5.e.(2},
6.d.(1}, and 6.d.(2} (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(j) Except when:
- 1. All MFIVs are closed and de-activated; AND
- 2. All MFRVs are:
2.a Closed and de-activated, or 2.b Closed and isolated by a closed manual valve; AND
- 3. All MFRVBVs are:
3.a Closed and de-activated, or 3.b Closed and isolated by a closed manual valve, or 3.c Isolated by two closed manual valves.
(q) Feedwater isolation only.
(r) Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.
(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.
CALLAWAY PLANT 3.3-45 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 7 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 5. Turbine Trip and Feedwater Isolation
- e. Steam Generator Water Level Low-Low(q)
(3) Not used.
(4) Containment 1m, 2m, 3m 4 N SR 3 3.2.1 s 2.0 psig Pressure Sf~ :33.2.5 Environmental SR:3 3.2.9 Allowance SR :U.2.10 Modifier (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.( 1), 5.e.(2),
6.d.( 1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
- 0) Except when:
- 1. All MFIVs are closed and de-activated; AND
- 2. All MFRVs are:
2.a Closed and de-activated, or 2.b Closed and isolated by a closed manual valve; AND
- 3. All MFRVBVs are:
3.a Closed and de-activated, or 3.b Closed and isolated by a closed manual valve, or 3.c Isolated by two closed manual valves.
(q) Feedwater isolation only.
CALLAWAY PLANT 3.3-46 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 8 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- a. Manual Initiation 1,2,3 1/pump P SR 3.32.8 NA
- b. Automatic 1,2,3 2 trains G SR 3.3.22 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)
- d. SG Water Level Low-Low (1) Steam 1,2,3 4 perSG D SR :U.2 1 ~ 20.6%(s) of Generator SR 3:)25 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Adverse Containment Environment)
(2) Steam 4 per SG D SR 3:; 21 ~ 16.6%(5) of Generator SR:U;)5 Narrow Range Water Level SR 3.32.9 Instrument Low-Low SR 3.3.2.10 Span (Normal Containment Environment)
(a) The Allowable Value defines the limiting safety system setting except for Functions 1 .e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),
6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(r) Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.
(s) 1. Ifthe as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-left setpOint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.
CALLAWAY PLANT 3.3-47 Amendment No. 202 ,
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page90f11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VAlUE(a)
- d. SG Water Level Low-Low (3) Not used.
(4) Containment 1,2,3 4 N SR 3.3.2.1 <; 2.0 psig Pressure - SR 3.3.2.5 Environmental SF'< 3.3.2.9 Allowance SR 3.3.2.10 Modifier
- e. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.
- f. Loss of Offsite 1,2,3 2 trains R SR 3.3.2.7 NA Power SR 3.3.2.10
- g. Trip of all Main 1(v),2(n),(v) 4(u),(w) J,M SR 3.3.2.8 NA Feedwater Pumps
- h. Auxiliary 1,2,3 3 0 SR 3.3.2.1 2! 20.64 psia Feedwater Pump SR 3:329 Suction Transfer SR 3.:32.10 on Suction SR 3.3.2.12 Pressure - low (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),
6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(n) Trip function may be blocked just before shutdown of the last operating main feedwater pump and restored just after the first main feedwater pump is put into service following performance of its startup trip test.
(u) During startup of the second main feedwater pump, the following exception applies: The requirement for four OPERABLE channels is met if two required channels are OPERABLE on the associated main feedwater pump in operation supplying feedwater to the SGs and two required channels are in the tripped condition on the second main feedwater pump.
(v) During removal of the first of two operating main feedwater pumps from service, the following exception applies:
(1) LCO 3.0.3 is not applicable for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for the channels associated with the first main feedwater pump, OR (2) The requirement for four OPERABLE channels is met if two required channels are OPERABLE on the associated main feedwater pump in operation supplying feedwater to the SGs and two required channels on the main feedwater pump to be removed from service are in the tripped condition.
(w) During removal of the first of two operating main feedwater pumps from service, the following exception applies: The requirement for four OPERABLE channels is met if two required channels are OPERABLE on the associated main feedwater pump in operation supplying feedwater to the SGs and two required channels on the main feedwater pump to be removed from service are in the tripped condition.
CALLAWAY PLANT 3.3-48 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 10 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(aJ
- 7. Automatic Switch over to Containment Sump
- a. Automatic 1,2,3,4 2 trains C SR 33.2.2 NA Actuation Logic SR :U2A and Actuation SR 3.3.213 Relays (SSPS)
- b. Refueling Water 1,2,3,4 4 K Sf" 3.3.2.1 235.2%
Storage Tank SR 3.3.25 (RWST) Level SH 3 329 Low Low SR 3.321 Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.
Safety Injection
- 8. ESFAS Interlocks
- a. Reactor Trip. P-4 1,2,3 2 per train, F SR 3.3.2.11 NA 2 trains
- b. Pressurizer 1,2,3 3 L 3.32.5 ~ 1981 psig Pressure, P-11 3.3.2.9
- 9. Automatic Pressurizer PORV Actuation
- a. Automatic 1,2,3 2 trains H SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.14 Relays (SSPS)
- b. Pressurizer 1,2,3 4 D SR 3.3.2.1 ,.;2350 psig Pressure - High SR 33.2.5 3.3.2.9 (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),
6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
CALLAWAY PLANT 3.3-49 Amendment No. 202 I
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 11 of 11 )
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 10. Steam Generator Blowdown and Sample Line Isolation
- a. Manual Initiation 1(1), 2(t), 3(1) 2 trains P SR :U,2,a NA (1 per MDAFW pump)
- b. Automatic 1(1),2(1),3(1) 2 trains Q SR 3.3.2.3 NA Actuation Logic and Actuation Relays (BOP ESFAS)
- c. Safety Injection 1(1),2(1),3(1) Refer to Function 1 (Safety Injection) for initiation functions and requirements.
- d. Loss of Offsite 1(1),2(1),3(t) 2 trains R SR :U.2,7 NA Power (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),
6,d,(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(t) Except when all Steam Generator Slowdown and Sample Line Isolation Valves are:
1, Closed and de-activated, or
- 2. Closed and isolated by a closed manual valve, or
- 3. Isolated by a combination of closed manual valve{s) and closed de-activated automatic valve(s).
CALLAWAY PLANT 3.3-50 Amendment No. 202 I
PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.
APPLICABILITY: MODES 1, 2 and 3.
ACTIONS
NOTE ----------------------------------------------------------
Separate Condition entry is allowed for each Function.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 Restore required 30 days one required channel channel to OPERABLE inoperable. status.
B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.8.
met.
(continued)
CALLAWAY PLANT 3.3-51 Amendment No. 202 I
PAM Instrumentation 3.3.3 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. One or more Functions with C.1 Restore all but one 7 days two or more required channel to OPERABLE channels inoperable. status.
D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C not Table 3.3.3-1 for the met. channel.
E. As required by Required E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action D.1 and referenced in Table 3.3.3-1. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> F. As required by Required F.1 Initiate action in Immediately Action D.1 and referenced accordance with in Table 3.3.3-1. Specification 5.6.S.
CALLAWAY PLANT 3.3-52 Amendment No. 202 ,
PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS
NOT E ----------------------------------------------------------
SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.
SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK. I n accordance with the Surveillance Frequency Control Program SR 3.3.3.2 --------------------------------- NOT E ---------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-53 Amendment No. 202
PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 2)
Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED REQUIRED FUNCTION CHANNELS ACTION D.1 2 E
- 1. Neutron Flux
- 2. Reactor Coolant System (RCS) Hot Leg 2 E Temperature (Wide Range)
- 3. RCS Cold Leg Temperature (Wide Range) 2 E
- 4. RCS Pressure (Wide Range) 2 E
- 5. Reactor Vessel Level Indicating System 2 F (RVLlS)
- 6. Containment Normal Sump Water Level 2 E
- 7. Containment Pressure (Normal Range) 2 E
- 8. Steam Line Pressure 2 per steam E generator
- 9. Containment Radiation Level (High Range) 2 F
- 10. Not Used
- 11. Pressurizer Water Level 2 E
- 12. Steam Generator Water Level (Wide Range) 4 E
- 13. Steam Generator Water Level (Narrow Range) 2 per steam E generator (continued)
CALLAWAY PLANT 3.3-54 Amendment No. 202 I
PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 2 of 2)
Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED REQUIRED FUNCTION CHANNELS ACTION D.1
- 14. Core Exit Temperature - Quadrant 1 2(a) E
- 15. Core Exit Temperature - Quadrant 2 2(a) E
- 16. Core Exit Temperature - Quadrant 3 2(a) E
- 17. Core Exit Temperature - Quadrant 4 2(a) E
- 18. Auxiliary Feedwater Flow Rate 4 E
- 19. Refueling Water Storage Tank Level 2 E (a) A channel consists of two core exit thermocouples (CETs).
CALLAWAY PLANT 3.3-55 Amendment No. 202 I
Remote Shutdown System 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown System LCO 3.3.4 The Remote Shutdown System Functions in Table 3,3.4-1 and the required auxiliary shutdown panel (ASP) controls shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS
NOTE ----------------------------------------------------------
Separate Condition entry is allowed for each Function and required ASP control.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.1 Restore required 30 days Functions inoperable. Function and required ASP controls to OPERABLE status.
One or more required ASP controls inoperable.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.3-56 Amendment No. 202 I
Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally energized. with the Surveillance Frequency Control Program SR 3.3.4.2 --------------------------------- NOTE ---------------------------
Only required to be performed in MODES 1 and 2 for the turbine-driven AFW pump.
Verify each required auxiliary shutdown panel control In accordance circuit and transfer switch is capable of performing the with the intended function. Surveillance Frequency Control Program SR 3.3.4.3 --------------------------------- NOTE --------------------------
- 1. Neutron detectors are excluded from CHANNEL CALIBRATION.
- 2. Reactor trip breaker and RCP breaker position indications are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION for each required In accordance instrumentation channel. with the i Surveillance Frequency Control Program CALLAWAY PLANT 3.3-57 Amendment No. 202
Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of 1)
Remote Shutdown System Functions
- 1. Source Range Neutron Flux(a) 1
- 2. Reactor Trip Breaker Position 1 per trip breaker
- 3. Pressurizer Pressure 1
- 4. RCS Wide Range Pressure 1
- 5. RCS Hot Leg Temperature 1
- 6. RCS Cold Leg Temperature 1
- 9. AFW Flow Rate 1
- 10. RCP Breaker Position 1 per pump
- 11. AFW Suction Pressure 1
- 12. Pressurizer Level 1 (a) Not required OPERABLE in MODE 1 or in MODE 2 above the P-6 setpoint.
CALLAWAY PLANT 3.3-58 Amendment No. 202 I
LOP DG Start Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation LCO 3.3.5 Four channels per 4.16-kV NB bus of the loss of voltage Function and four channels per 4.16-kV NB bus of the degraded voltage Function shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4, When associated DG is required to be OPERABLE by LCO 3.8.2, "AC Sources - Shutdown."
ACTIONS
NOTE ----------------------------------------------------------
Separate Condition entry is allowed for each Function.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 ------------ NOTE ----------
one channel per bus The inoperable channel inoperable. may be bypassed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for surveillance testing of other channels.
Place channel in trip. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> B. One or more Functions with B.1 Declare associated load Immediately two or more channels per shedder and emergency bus inoperable. load sequencer (LSELS) inoperable.
QB Required Action and associated Completion Time of Condition A not met.
CALLAWAY PLANT 3.3-59 Amendment No. 202 I
LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Tie breakers between 480 Vac buses NG01 and In accordance NG03 and between 480 Vac buses NG02 and NG04 with the shall be verified open. Surveillance Frequency Control Program SR 3.3.5.2 --------------------------------- NOTE ---------------------------
Verification of time delays is not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3 Perform CHANNEL CALIBRATION with nominal Trip In accordance Setpoint and Allowable Value as follows: with the Surveillance
- a. Loss of voltage Allowable Value 83 +0, -8.3V Frequency (120V Bus) with a time delay of 1.0 + 0.2, Control Program
-0.5 sec.
Loss of voltage nominal Trip Setpoint 83V
( 120V Bus) with a time delay of 1.0 sec.
- b. Degraded voltage Allowable Value 107.47 +/- 0.38V (120V Bus) with a time delay of 119 +/- 11.6 sec.
Degraded voltage nominal Trip Setpoint 107.47V (120V Bus) with a time delay of 119 sec.
SR 3.3.5.4 Verify LOP DG Start ESF RESPONSE TIMES are In accordance within limits. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-60 Amendment No. 202
Containment Purge Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION 3.3.6 Containment Purge Isolation Instrumentation LCO 3.3.6 The Containment Purge Isolation instrumentation for each Function in Table 3.3,6-1 shall be OPERABLE.
APPLICABILITY: According to Table 3.3.6-1.
ACTIONS
NOT E ----------------------------------------------------------
Separate Condition entry is allowed for each Function.
COMPLETION CONDITION REQUIRED ACTION TIME A. One radiation monitoring A.1 Restore the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> channel inoperable. channel to OPERABLE status.
(continued)
CALLAWAY PLANT 3.3-61 Amendment No. 202 I
Containment Purge Isolation Instrumentation 3.3.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. ------------- NOTE ------------ ------------------- NOTE ------------------
Only applicable in MODE 1, Containment mini-purge supply and 2,3, or 4. exhaust valves closed to satisfy Required Action B.1 may be opened intermittently under administrative One or more Functions with controls, provided Table 3.3.6-1 one or more manual Functions 2 and 4 are OPERABLE.
channels or automatic actuation trains inoperable. B.1 Place and maintain Immediately containment purge supply and exhaust valves in closed position.
Both radiation monitoring channels inoperable.
Required Action and associated Completion Time of Condition A not met.
(continued)
CALLAWAY PLANT 3.3-62 Amendment No. 205
Containment Purge Isolation Instrumentation 3.3.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. ------------- NOTE ------------ C.1 Place and maintain Immediately Only applicable during containment purge CORE ALTERATIONS or supply and exhaust movement of irradiated fuel valves in closed position.
assemblies within containment. OR C.2 Enter applicable Immediately One or more manual Conditions and Required channels inoperable. Actions of LCO 3.9.4, "Containment Penetrations," for containment purge supply and exhaust valves made inoperable by isolation instrumentation.
CALLAWAY PLANT 3.3-63 Amendment No. 202 I
Containment Purge Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS
NOTE ----------------------------------------------------------
Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge Isolation Function.
SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. In accordance
- with the Surveillance Frequency Control Program SR 3.3.6.2 --------------------------------- NOT E ---------------------------
The continuity check may be excluded.
Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4 --------------------------------- NOTE ---------------------------
Verification of setpoint is not required.
Perform TADOT. In accordance
- with the
- Surveillance Frequency Control Program CALLAWAY PLANT 3.3-64 Amendment No. 202
Containment Purge Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.6.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.6 Verify Containment Purge Isolation ESF RESPONSE In accordance TIMES are within limits. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-65 Amendment No. 202
Containment Purge Isolation Instrumentation 3.3.6 TABLE 3.3.6-1 (PAGE 1 OF 1)
Containment Purge Isolation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE NOMINAL FUNCTION CONDITIONS CHANNELS REQUIREMENTS TRIP SETPOINT
- 1. Manual 1,2,3,4, 2 SR 3.3.6.4 NA Initiation (a). (b)
- 2. Automatic 1,2.3,4 2 trains SR 3.36.2 NA Actuation SR 3.3.66 Logic and Actuation Relays (BOP ESFAS)
- 3. Containment 1,2,3,4 2 SR 3.3.6.1 (c)
Purge SR 3.3.6.3 Exhaust SR 3.3.6.5 Radiation Gaseous
- 4. Containment Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3.a, for all initiation functions and Isolation requirements.
Phase A (a) During CORE ALTERATIONS.
(b) During movement of irradiated fuel assemblies within containment.
(c) Set to ensure ODCM limits are not exceeded.
CALLAWAY PLANT 3,3-66 Amendment No. 202 I
CREVS Actuation Instrumentation 3.3.7 3.3 INSTRUMENTATION 3.3.7 Control Room Emergency Ventilation System (CREVS) Actuation Instrumentation LCO 3.3.7 The CREVS actuation instrumentation for each Function in Table 33.7-1 shall be OPERABLE.
APPLICABILITY: According to Table 3.3.7-1.
ACTIONS
NOTE ---------------------------------------------------------
Separate Condition entry is allowed for each Function.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions with A.1 Place one CREVS train 7 days one channel or train in Control Room inoperable. Ventilation Isolation Signal (CRVIS) mode.
(Continued)
CALLAWAY PLANT 3.3-67 Amendment No. 202 I
CREVS Actuation Instrumentation 3.3.7 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. ------------- NOTE ------------- B.1.1 Place one CREVS train Immediately Not applicable to in CRVIS mode.
Function 3.
AND One or more Functions with B.1.2 Enter applicable Immediately two channels or two trains Conditions and Required inoperable. Actions of LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS)", for one CREVS train made inoperable by inoperable CREVS actuation instrumentation.
OR B.2 Place both trains in Immediately CRVIS mode.
~contlnuea)
CALLAWAY PLANT 3.3-68 Amendment No. 202 I
CREVS Actuation Instrumentation 3.3.7 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. Both radiation monitoring C.1.1 Enter applicable Immediately channels inoperable. Conditions and Required Actions of LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS)," for one CREVS train made inoperable by inoperable CREVS actuation instrumentation.
AND C.1.2 Place one CREVS train 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> in CRVIS mode.
OR C.2 Place both trains in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> CRVIS mode.
D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for Conditions A, B, AND or C not met in MODE 1, 2, 3, or 4. D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E. Required Action and E.1 Suspend CORE Immediately associated Completion ALTERATIONS.
Time for Conditions A, B, or C not met during CORE AND ALTERATIONS or during movement of irradiated fuel E.2 Suspend movement of Immediately assemblies. irradiated fuel assemblies.
CALLAWAY PLANT 3.3-69 Amendment No. 202 I
CREVS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS
NOT E ----------------------------------------------------------
Refer to Table 3.3.1-1 to determine which SRs apply for each CREVS Actuation Function.
SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.3 --------------------------------- NOTE ---------------------------
The continuity check may be excluded.
Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.4 --------------------------------- NOT E ---------------------------
Verification of setpoint is not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.3-70 Amendment No. 202
CREVS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.7.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.7.6 --------------------------------- NOTE ---------------------------
Radiation monitor detectors are excluded from response time testing.
Verify Control Room Ventilation Isolation ESF In accordance RESPONSE TIMES are within limits with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-71 Amendment No. 202
CREVS Actuation Instrumentation 3.3.7 Table 3.3.7-1 (page 1 of 1)
CREVS Actuation Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT
- 1. Manual 1,2,3,4, 2 SR 33.7.4 NA Initiation (a), and (c)
- 2. Automatic 1,2,3,4, 2 trains SR :3.3.7.3 NA Actuation (a), and (c)
Logic and Actuation (a) 2 trains SR 33.7.6 NA Relays (BOP ESFAS)
- 3. Control Room 1,2,3,4, 2 SR 3.3.7.1 (b)
Radiation and (a) SR 3.3.7.2 Control Room SR 3.3.7.5 Air Intakes (a) 2 SR 3.3.7.6 (b)
- 4. Containment Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3.a, for all initiation functions and Isolation - requirements.
Phase A
- 5. Fuel Building Refer to LCO 3.3.8, "EES Actuation Instrumentation," for all initiation functions and Exhaust requirements.
Radiation-Gaseous (a) During CORE ALTERATIONS or during movement of irradiated fuel assemblies within containment.
(b) Nominal Trip Setpoint concentration value (flCi/cm 3 ) shall be established such that the actual submersion dose rate would not exceed 2 mRlhr in the control room.
(c) During movement of irradiated fuel assemblies in the fuel building.
CALLAWAY PLANT 3.3-72 Amendment No. 202 I
EES Actuation Instrumentation 3.3.8 3.3 INSTRUMENTATION 3.3.8 Emergency Exhaust System (EES) Actuation Instrumentation LCO 3.3.8 The EES actuation instrumentation for each Function in Table 3.3.8-1 shall be OPERABLE.
APPLICABILITY: According to Table 3.3.8-1.
ACTIONS
NOT ES --------------------------------------------------------
- 1. LCO 3.0.3 is not applicable.
- 2. Separate Condition entry is allowed for each Function.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more Functions A.1 Place one EES train in 7 days with one channel or train the Fuel Building inoperable. Ventilation Isolation Signal (FBVIS) mode.
AND A.2 Place one CREVS train 7 days in Control Room Ventilation Isolation Signal (CRVIS) mode.
(contlnuea)
CALLAWAY PLANT 3.3-73 Amendment No. 202 I
EES Actuation Instrumentation 3.3.8 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. ------------- NOTE ------------ B.1.1 Place one EES train in Immediately Not applicable to the FBVIS mode and Function 3. one CREVS train in the CRVIS mode.
One or more Functions AND with two channels or two trains inoperable. B.1.2 Enter applicable Immediately Conditions and Required Actions of LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS)," for one CREVS train made inoperable and enter applicable Conditions and Required Actions of LCO 3113, "Emergency Exhaust System (EES),"
for one EES train made inoperable by inoperable EES actuation instrumentation.
B.2 Place both EES trains in Immediately the FBVIS mode and both CREVS trains in the CRVIS mode.
CALLAWAY PLANT 3.3-74 Amendment No. 202 I
EES Actuation Instrumentation 3.3.8 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. Both radiation monitoring C.1.1 Enter applicable Immediately channels inoperable. Conditions and Required Actions of LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS}," for one CREVS train made inoperable and enter applicable Conditions and Required Actions of LCO 3.7.13, "Emergency Exhaust System (EES),"
for one EES train made inoperable by inoperable EES actuation instrumentation.
AND C.1.2 Place one EES train in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the FBVIS mode and one CREVS train in the CRVIS mode.
OR C.2 Place both EES trains in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the FBVIS mode and both CREVS trains in the CRVIS mode.
D. Required Action and D.1 Suspend movement of Immediately associated Completion irradiated fuel Time for Conditions A, B, assemblies in the fuel or C not met during building.
movement of irradiated fuel assemblies in the fuel building.
CALLAWAY PLANT 3.3-75 Amendment No. 202 I
EES Actuation Instrumentation 3.3.8 SURVEILLANCE REQUIREMENTS
NOT E ----------------------------------------------------------
Refer to Table 3.3.8-1 to determine which SRs apply for each EES Actuation Function.
SU RVEI LLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.8.3 --------------------------------- NOTE ---------------------------
The continuity check may be excluded.
Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.4 --------------------------------- NOTE ---------------------------
Verification of setpoint is not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program (continUed)
CALLAWAY PLANT 3.3-76 Amendment No. 202
EES Actuation Instrumentation 3.3.8 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.3.8.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.8.6 -------------------------- NOTE ---------------------
Radiation monitor detectors are excluded from response time testing.
Verify Fuel Building Ventilation Exhaust ESF In accordance RESPONSE TIMES are within limits. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-77 Amendment No. 204
EES Actuation Instrumentation 3.3.8 Table 3.3.8-1 (page 1 or 1)
EES Actuation Instrumentation APPLICABLE MODES OR SPECIFIED REQUIRED SURVEIl.LANCE NOMINAl. TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT
- 1. Manual (al 2 SR 3.3.8.4 NA Initiation
- 2. Automatic (a) 21rains SR 3.3.8.3 NA Actualion SR 3.3.8.6 Logic and Actualion Relays (BOP ESFAS)
- 3. Fuel (a) 2 SR 3.3.8.1 (b)
Building SR 33.8.2 Exhaust SR 3.3.8.5 Radiation SR 3.3.86
- Gaseous (a) During movement of irradialed ruel assemblies in the fuel buildiflg.
(b) Nominal Trip Selpoin! concentration value ("Ci/om a) shall be established such that the aclual submersion dose rate would not exceed 4 mRlhr in the fuel building.
CALLAWAY PLANT 3.3-78 Amendment No. 204
BDMS 3.3.9 3.3 INSTRUMENTATION 3.3.9 Boron Dilution Mitigation System (BDMS)
LCO 3.3.9 Two trains of the BDMS shall be OPERABLE and one RCS loop shall be in operation.
APPLICABILITY: MODES 2 (below P-6 (Intermediate Range Neutron Flux) interlock), 3, 4, and 5.
NOTE ----------------------------------------
The boron dilution flux multiplication signal may be blocked:
- 1. During subcritical physics testing;
- 2. During control bank movement in MODE 2 (below P-6 (Intermediate Range Neutron Flux) interlock);
- 3. During control bank movement in MODE 3;
- 4. During shutdown bank movement in MODE 3.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One train inoperable. A.1 Restore train to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
(continued)
CALLAWAY PLANT 3.3-79 Amendment No. 202 I
BDMS 3.3.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Two trains inoperable. B.1 **********. NOTE _._-.__**__*
Plant temperature changes are allowed provided the temperature Required Action and change is accounted for associated Completion Time in the calculated SDM.
of Condition A not met.
Suspend operations Immediately involving positive reactivity additions.
AND B.2 Perform SR 3.1.1.1. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND B.3.1 Close and secure 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> unborated water source isolation valves.
AND B.3.2 Verify unborated water Once per 31 days source isolation valves are closed and secured.
(continued)
CALLAWAY PLANT 3.3-80 Amendment No. 202 I
BDMS 3.3.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. No RCS loop in operation. C.1 Close and secure 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> unborated water source isolation valves.
AND C.2 Verify unborated water Once per 31 days source isolation valves are closed and secured.
CALLAWAY PLANT 3.3-81 Amendment No. 202 I
BDMS 3.3.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.9.2 --------------------------------- NOTE ---------------------------
Only required to be performed in MODE 5.
Verify BGV0178 is secured in the closed position. In accordance with the Surveillance Frequency Control Program SR 3.3.9.3 --------------------------------- NOT E ---------------------------
Not required to be performed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after reducing power below P-6 interlock.
Perform COT and verify nominal flux multiplication In accordance setpoint of 1.7. with the Surveillance Frequency Control Program SR 3.3.9.4 --------------------------------- NOTE ---------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-82 Amendment No. 202
BDMS 3.3.9 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.9.5 Verify the centrifugal charging pump suction valves In accordance from the RWST open and the CVCS volume control with the tank discharge valves close in less than or equal to Surveillance 30 seconds on a simulated or actual actuation signal. Frequency Control Program SR 3.3.9.6 Verify one RCS loop is in operation. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.3-83 Amendment No. 202
RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified below:
- a. Pressurizer pressure is greater than or equal to the limit specified in the COLR',
- c. RCS total flow rate >_382,630 gpm.
APPLICABILITY: MODE 1.
NOTE ------------- --------------------
Pressurizer pressure limit does not apply during:
- a. THERMAL POWER ramp > 5% RTP per minute; or
- b. THERMAL POWER step > 10% RTP.
ACTIONS COMPLETIONTIME CONDITION REQUIRED ACTION TIME A. One or more RCS DNB A.1 Restore RCS DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not within limits, parameter(s) to within limit.
B. Required Action and b B.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
CALLAWAY PLANT 3.4-1 Amendment No. 183
RCS Pressure, Temperature, and Flow ONB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is greater than or equal to In accordance the limit specified in the COLR. with the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is less than or equal In accordance to the limit specified in the COLR. with the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is ~ 382,630 gpm. In accordance with the Surveillance Frequency Control Program SR 3.4.1.4 --------------------------------- NOTE ---------------------------
Calculated rather than verified by precision heat balance when performed prior to THERMAL POWER exceeding 75% RTP.
Verify by precision heat balance that RCS total flow Once after each rate is ~ 382,630 gpm. refueling prior to THERMAL POWER exceeding 75%
RTP In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT Amendment No. 202
RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each operating RCS loop average temperature (Tavg) shall be ~ 551°F.
APPLICABILITY: MODE 1, MODE 2 with keff ~ 1.0.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Tavg in one or more A.1 Be in MODE 2 with keff 30 minutes operating RCS loops not < 1.0.
within limit.
SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each operating loop ~ 551°F. In accordance
- with the I Surveillance I Frequency
~ontrol Program CALLAWAY PLANT 3.4-3 Amendment No. 202
RCS P/T Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (PIT) Limits LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in the PTLR.
APPLICABILITY: At all times.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. -NOTE- A.1 Restore parameter(s) to 30 minutes Required Action A.2 shall within limits.
be completed whenever this Condition is entered. AND A.2 Determine RCS is 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Requirements of LCO not acceptable for continued met in MODE 1, 2, 3, or 4. operation.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met.
B.2 Be in MODE 5 with RCS 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> pressure < 500 psig.
(continued)
CALLAWAY PLANT 3.4-4 Amendment No. 133
RCS PIT Limits 3.4.3 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. ------------- NOTE ------------ C.1 Initiate action to restore Immediately Required Action C.2 shall parameter(s) to within be completed whenever limits.
this Condition is entered.
AN D Requirements of LCO not C.2 Determine RCS is Prior to entering met any time in other than acceptable for continued MODE4 MODE 1,2,3, or4. operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 --------------------------------- NOT E ---------------------------
Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.
Verify RCS pressure, RCS temperature. and RCS In accordance heatup and cooldown rates are within the limits with the specified in the PTLR. Surveillance Frequency Control Program CALLAWAY PLANT 3.4-5 Amendment No. 202
RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.
APPLICABILITY: MODES 1 and 2.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-6 Amendment No. 202
RCS Loops - MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops - MODE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and either
- a. Two RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal; or
- b. One RCS loop shall be in operation when the Rod Control System is not capable of rod withdrawal.
NOTE All reactor coolant pumps may be removed from operation for< 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:
- a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and
- b. Core outlet temperature is maintained at least 100 F below saturation temperature.
APPLICABILITY: MODE 3.
ACTIONS CONDITION REQUIRED ACTION TIME A. One required RCS loop A.1 Restore required RCS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. loop to OPERABLE status.
B. Required Action and B.1 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met.
(continued)
K> CALLAWAY PLANT 3.4-7 Amendment No. 149
RCS Loops - MODE 3 3.4.5 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION C. One required RCS loop not C.1 Restore required RCS 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> in operation with Rod loop to operation.
Control System capable of rod withdrawal. OR C.2 Place the Rod Control 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> System in a condition incapable of rod withdrawal.
D. Required RCS loops D.1 Place the Rod Control Immediately inoperable. System in a condition incapable of rod OR withdrawal.
No RCS loop in operation. AND D.2 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet SDM of LCO 3.1.1.
AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.
CALLAWAY PLANT 3.4-8 Amendment No. 149
RCS Loops - MODE 3 3.4.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify steam generator secondary side narrow range In accordance water levels are ~ 7% for required RCS loops. with the Surveillance Frequency Control Program SR 3.4.5.3 Verify correct breaker alignment and indicated power In accordance are available to the required pump that is not in with the operation. I Surveillance Frequency Control Program I
CALLAWAY PLANT 3.4-9 Amendment No. 202
RCS Loops - MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops - MODE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.
NOTES
- 1. All reactor coolant pumps (RCPs) and RHR pumps may be removed from operation for s 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:
- a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and
- b. Core outlet temperature is maintained at least 10F below saturation temperature.
< 2750 F unless the secondary side water temperature of each steam generator (SG) is s 500 F above each of the RCS cold leg temperatures.
APPLICABILITY: MODE 4.
ACTIONS _
CONDITION REQUIRED ACTION COMPLETION TIME A. One required loop A.1 Initiate action to restore a Immediately inoperable. second loop to OPERABLE status.
AND A.2 --------- NOTE------
Only required if one RHR loop is OPERABLE.
Be in MODE 5. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> (continued)
CALLAWAY PLANT 3.4-1 0 Amendment No. 149
RCS Loops - MODE 4 3.4.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Required loops inoperable. B.1 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less No RCS or RHR loop in than required to meet operation. SDM of LCO 3.1.1.
AND B.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.
I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.6.2 Verify SG secondary side narrow range water levels In accordance are ~ 7% for required RCS loops. with the Surveillance Frequency Control Program SR 3.4.6.3 Verify correct breaker alignment and indicated power In accordance are available to the required pump that is not in with the operation. Surveillance Frequency Control Program CALLAWAY PLANT 3.4-11 Amendment No. 202
RCS Loops - MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops - MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:
- b. The secondary side wide range water level of at least two steam generators (SGs) shall be 2 86%.
~~--------NOTES --------------
- 1. The RHR pump of the loop in operation may be removed from operation for < 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:
- a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and
- b. Core outlet temperature is maintained at least 10OF below saturation temperature.
- 2. One required RHR loop may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing provided that the other RHR loop is OPERABLE and in operation.
- 3. No reactor coolant pump shall be started with any RCS cold leg temperature < 2750 F unless the secondary side water temperature of each SG is < 500 F above each of the RCS cold leg temperatures.
- 4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.
APPLICABILITY: MODE 5 with RCS loops filled.
CALLAWAY PLANT 3.4-12 Amendment No. 168
RCS Loops - MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One RHR loop inoperable. A.1 Initiate action to restore Immediately a second RHR loop to AND OPERABLE status.
Required SGs secondary OR side water levels not within limits. A.2 Initiate action to restore Immediately required SG secondary side water levels to within limits.
B. Required RHR loops B.1 Suspend operations that Immediately inoperable. would cause introduction into the RCS, coolant OR with boron concentration less than required to No RHR loop in operation. meet SDM of LCO 3.1.1.
AND B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.
CALLAWAY PLANT 3.4-1 3 Amendment No. 149
RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side wide range water level is In accordance
~ 86% in required SGs. with the Surveillance Frequency Control Program SR 3.4.7.3 Verify correct breaker alignment and indicated power In accordance are available to the required RHR pump that is not in with the operation. Surveillance Frequency Control Program CALLAWAY PLANT 3.4-14 Amendment No. 202
RCS Loops - MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops - MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation.
------------------------- -NOTES-----------------
- 1. All RHR pumps may be removed from operation for < 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> provided:
- a. The core outlet temperature is maintained at least 10F below saturation temperature.
- b. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and
- c. No draining operations to further reduce the RCS water volume are permitted.
- 2. One RHR loop may be inoperable for
- 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing provided that the other RHR loop is OPERABLE and in operation.
APPLICABILITY: MODE 5 with RCS loops not filled.
ACTIONS CONDITION REQUIRED ACTION TIME A. One RHR loop inoperable. A.1 Initiate action to restore Immediately RHR loop to OPERABLE status.
(continued)
CALLAWAY PLANT 3.4-15 Amendment No. 164
RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Required RHR loops B.1 Suspend operations that Immediately inoperable. would cause introduction into the RCS, coolant with boron concentration less than required to No RHR loop in operation. meet SDM of LCO 3.1.1.
AND B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance are available to the required RHR pump that is not in with the operation. Surveillance Frequency Control Program CALLAWAY PLANT 3.4-16 Amendment No. 202
Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:
- a. Pressurizer water level s 92%; and
- b. Two groups of backup pressurizer heaters OPERABLE with the capacity of each group 2 150 kW.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Pressurizer water level not A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> within limit.
AND A.2 Fully insert all rods. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND A.3 Place Rod Control 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> System in a condition incapable of rod withdrawal.
AND A.4 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> B. One required group of B.1 Restore required group 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> backup pressurizer heaters of backup pressurizer inoperable. heaters to OPERABLE status.
(continued)
CALLAWAY PLANT 3.4-1 7 Amendment No. 133
Pressurizer 3.4.9 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition B not AND met.
C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is s; 92%. In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of backup In accordance pressurizer heaters is :?: 150 kW. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-18 Amendment No. 202
Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings
~ 2411 psig and::; 2509 psig.
APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures> 275°F.
NOTES -------------------------------------------
The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> RCS cold leg Two or more pressurizer temperature::; 275°F.
safety valves inoperable.
CALLAWAY PLANT 3.4-19 Amendment No. 188
Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE In accordance with in accordance with the Inservice Testing Program. the Inservice Following testing, lift settings shall be within +/- 1% of Testing Program 2460 psig.
CALLAWAY PLANT 3.4-20 Amendment No. 137 SEP 2 5 2Q00
Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)
LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS
NOTE -~---------------------------------------------------------
Separate Condition entry is allowed for each PORV and each block valve.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more PORVs A.1 Close and maintain 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable solely due to power to associated excessive seat leakage. block valve.
B. One PORV inoperable for B.1 Close associated block 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> reasons other than valve.
excessive seat leakage.
AND B.2 Remove power from 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> associated block valve.
AND B.3 Restore PORV to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
(continued)
CALLAWAY PLANT 3.4-21 Amendment No. 188
Pressurizer PORVs 3.4.11 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION C. One block valve NOTE-----
inoperable. Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2.
C.1 Place associated PORV 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> in manual control.
AND C.2 Restore block valve to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A, B, or C not met. AND D.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. Two PORVs inoperable for E.1 Close associated block 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> reasons other than valves.
excessive seat leakage.
AND E.2 Remove power from 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> associated block valves.
AND E.3 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND E.4 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)
CALLAWAY PLANT 3.4-22 Amendment No. 137 SEP 2 5 2000
Pressurizer PORVs 3.4.11 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME F. More than one block valve ------------------- NOTE ------------------
inoperable. Required Action F.1 does not apply when block valve is inoperable solely as a result of complying with Required Action B.2 or E.2.
F.1 Restore one block valve 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to OPERABLE status.
G Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition F not AND met.
8.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.4-23 Amendment No. 188
Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------------------- NOT E --------------------------
Not required to be performed with block valve closed in accordance with the Required Actions of this LCO.
Perform a complete cycle of each block valve. In accordance with the Surveillance Frequency Control Program SR 3.4.11.2 Perform a complete cycle of each PORV. In accordance with the Inservice Testing Program CALLAWAY PLANT 3.4-24 Amendment No. 202
COMS 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Cold Overpressure Mitigation System (COMS)
LCO 3.4.12 COMS shall be OPERABLE with a maximum of zero safety injection pumps, one Emergency Core Cooling System (ECCS) centrifugal charging pump, and the normal charging pump capable of injecting into the RCS and the accumulators isolated and one of the following pressure relief capabilities:
- a. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or
- b. Two residual heat removal (RHR) suction relief valves with setpoints 2 436.5 psig and ~ 463.5 psig, or
- c. One PORV with a lift setting within the limits specified in the PTLR and one RHR suction relief valve with a setpoint 2 436.5 psig and
~ 463.5 psig, or
N0 TES --------------------------------------------
- 1. Two ECCS centrifugal charging pumps may be made capable of injecting for~ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for pump swap operations.
- 2. One or more safety injection pumps may be made capable of injecting in MODES 5 and 6 when the RCS water level is below the top of the reactor vessel flange for the purpose of protecting the decay heat removal function.
- 3. Accumulator may be unisolated when accumulator pressure is less than the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.
APPLICABILITY: MODE 4 with any RCS cold leg temperature ~ 275°F, MODE 5, MODE 6 when the reactor vessel head is on.
CALLAWAY PLANT 3.4-25 Amendment No. 210
COMS 3.4.12 ACTIONS
N0 TE -----------------------------------------------------------
LCO 3.0.4.b is not applicable when entering MODE 4.
COMPLETION CONDITION REQUIRED ACTION TIME A One or more safety A.1 Initiate action to verify a Immediately injection pumps capable of maximum of zero safety injecting into the RCS. injection pumps are capable of injecting into the RCS.
B. Two ECCS centrifugal 8.1 Initiate action to verify a Immediately charging pumps capable of maximum of one ECCS injecting into the RCS. centrifugal charging pump and the normal charging pump capable of injecting into the RCS.
C. An accumulator not isolated C.1 Isolate affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> when the accumulator accumulator.
pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.
(contmued)
CALLAWAY PLANT 3.4-26 Amendment No. 210
COMS 3.4.12 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME D. Required Action and D.1 Increase all RCS cold 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion leg temperatures to Time of Condition C not > 275°F.
met.
OR D.2 Depressurize affected 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.
E. One required RCS relief E.1 Restore required RCS 7 days valve inoperable in relief valve to MODE4. OPERABLE status.
F. One required RCS relief F.1 Restore required RCS 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> valve inoperable in relief valve to MODE 5 or6. OPERABLE status.
G Two required RCS relief G1 Depressurize RCS and 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> valves inoperable. establish RCS vent of
~ 2.0 square inches.
OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met.
OR COMS inoperable for any reason other than Condition A, B, C, D, E, or F.
CALLAWAY PLANT 3.4-27 Amendment No. 188
COMS 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of zero safety injection pumps are In accordance capable of injecting into the RCS. with the Surveillance Frequency Control Program SR 3.4.12.2 Verify a maximum of one ECCS centrifugal charging In accordance pump and the normal charging pump capable of with the injecting into the RCS. Surveillance Frequency Control Program SR 3.4.12.3 Verify each accumulator is isolated when In accordance accumulator pressure is greater than or equal to the with the maximum RCS pressure for the existing RCS cold Surveillance leg temperature allowed by the P/T limit curves Frequency provided in the PTLR. Control Program SR 3.4.12.4 Verify RHR suction isolation valves are open for each In accordance required RHR suction relief valve. with the Surveillance Frequency Control Program SR 3.4.12.5 Verify required RCS vent::::: 2.0 square inches open. In accordance with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.4-28 Amendment No. 210
COMS 3.4.12 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.12.6 Verify PORV block valve is open for each required In accordance PORV. with the Surveillance Frequency Control Program SR 3.4.12.7 Not used.
SR 3.4.12.8 --------------------------------- NOTE ---------------------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after decreasing any RCS cold leg temperature to ~ 275°F.
Perform a COT on each required PORV, excluding In accordance actuation. with the Surveillance Frequency Control Program SR 3.4.12.9 Perform CHANNEL CALIBRATION for each required In accordance PORV actuation channel. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-29 Amendment No. 202
RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:
- a. No pressure boundary LEAKAGE;
- b. 1 gpm unidentified LEAKAGE;
- c. 10 gpm identified LEAKAGE; and I
- d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. RCS operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> LEAKAGE not within limits within limits.
'for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met.
B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Pressure boundary LEAKAGE exists.
OR Primary to secondary LEAKAGE not within limit.
CALLAWAY PLANT 3.4-30 Amendment No. 168
RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 -------------------------- NOT ES ------------------------------
- 1. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
- 2. Not applicable to primary to secondary LEAKAGE Verify RCS operational LEAKAGE is within limits by In accordance performance of RCS water inventory balance. with the Surveillance Frequency Control Program SR 3.4.13.2 -------------------------- NOTE -----------------------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Verify primary to secondary LEAKAGE is s 150 In accordance gallons per day through anyone SG. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-31 Amendment No. 202
RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit.
APPLICABILITY: MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) flow path when in, or during the transition to or from, the RHR mode of operation.
ACTIONS NOTES
- 1. Separate Condition entry is allowed for each flow path.
- 2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.
CONDITION REQUIRED ACTION COMPLETION A. One or more flow paths A.1 - NOTE with leakage from one or Each valve used to satisfy more RCS PlVs not within Required Action A.1 must limit. have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary.
Isolate the high pressure 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> portion of the affected system from the low pressure portion by use of one deactivated remote manual or check valve.
AND A.2 Restore RCS PIV to within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> limits.
(continued)
CALLAWAY PLANT 3.4-32 Amendment No. 133
RCS PIV Leakage 3.4.14 ACTION (continued)
CONDITION REQUIRED ACTION COMPLETION B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for Condition A not AND met.
B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> C. RHR suction isolation valve C.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> interlock function penetration by use of inoperable. one deactivated remote manual valve.
CALLAWAY PLANT 3.4-33 Amendment No. 133
RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 --------------------------------- NOT ES -------------------------
- 1. Not required to be performed in MODES 3 and 4.
- 2. Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.
- 3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.
Verify leakage from each RCS PIV is equivalent to In accordance with
~ 0.5 gpm per nominal inch of valve size up to a the Inservice maximum of 5 gpm at an RCS pressure 2 2215 psig Testing Program and ~ 2255 psig.
In accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more and if leakage testing has not been performed in the previous 9 months (continued)
CALLAWAY PLANT 3.4-34 Amendment No. 202
RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR3.4.14.1 (continued) Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following check valve actuation due to flow through the valve SR 3.4.14.2 Verify RHR suction isolation valve interlock prevents In accordance the valves from being opened with a simulated or with the actual RCS pressure signal ~ 425 psig except when Surveillance the valves are open to satisfy LCO 3.4.12. Frequency Control Program CALLAWAY PLANT 3.4-35 Amendment 202
RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:
- a. The containment sump level and flow monitoring system;
- b. One containment atmosphere particulate radioactivity monitor; and
- c. The containment cooler condensate monitoring system. I APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. Required containment sump A.1 NOTE------
level and flow monitoring Not required until system inoperable. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND A.2 Restore required 30 days containment sump level and flow monitoring system to OPERABLE status.
(continued)
CALLAWAY PLANT 3.4-36 Amendment No. 175
RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)
CONDITION I
REQUIRED ACTION COMPLETION TIME TIME B. Required containment B.1.1 Analyze samples of the Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> atmosphere particulate containment atmosphere.
radioactivity monitor inoperable. OR B.1.2 NOTE------ -----
Not required until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND B.2.1 Restore required 30 days I containment atmosphere particulate radioactivity monitor to OPERABLE status.
OR I.
B.2.2 Verify containment air 30 days cooler condensate monitoring system is OPERABLE.
tcontinueac)
CALLAWAY PLANT 3.4-37 Amendment No. 175
RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)
COMPLETION TIME CONDITION REQUIRED ACTION TIME C. Required containment C.1 Perform SR 3.4.15.1. Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> cooler condensate monitoring system OR inoperable.
C.2 NOTE------
Not required until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> I
D. Required containment D.1 Restore required 30 days atmosphere particulate containment atmosphere radioactivity monitor particulate radioactivity inoperable. monitor to OPERABLE status.
AND OR Required containment cooler condensate D.2 Restore required 30 days monitoring system containment cooler inoperable, condensate monitoring system to OPERABLE status.
E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> F.. All required monitoring F.1 Enter LCO 3.0.3. Immediately methods inoperable.
CALLAWAY PLANT 3.4-38 Amendment No. 175
RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance containment atmosphere particulate radioactivity with the monitor. Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance atmosphere particulate radioactivity monitor. with the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance containment sump level and flow monitoring system. with the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance containment atmosphere particulate radioactivity with the monitor. Surveillance Frequency Control Program SR 3.4.15.5 Perform CHANNEL CALIBRATION of the required In accordance containment cooler condensate monitoring system. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-39 Amendment No. 202
RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 RCS DOSE EQUIVALENT 1-131 and DOSE EQUIVALENT XE-133 specific activity shall be within limits.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COM PLETION TIME CONDITION REQUIRED ACTION TIME A. DOSE EQUIVALENT ------------- NOTE ----------
1-131 not within limit. LCO 3.0.4.c is applicable.
A.1 Verify DOSE Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> EQUIVALENT 1-131 60 ipCi/gm.
AND A.2 Restore DOSE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> EQUIVALENT 1-1031 to within limit.
B. DOSE EQUIVALENT ------------- NOTE ----------
XE-133 not within limit. LCO 3.0.4.c is applicable.
B.1 Restore DOSE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> EQUIVALENT XE-133 to within limit.
(continued)
CALLAWAY PLANT 3.4-40 Amendment No. 178
RCS Specific Activity 3.4.16 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A orB AND not met.
C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR DOSE EQUIVALENT 1-131
> 60 J.!Ci/gm.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 --------------------------------- N0 TE ----------------------------
Only required to be performed in MODE 1.
Verify reactor coolant DOSE EQUIVALENT XE-133 In accordance specific activity :s; 225 J.!Ci/gm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.4-41 Amendment No. 202
RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.16.2 --------------------------------- NOTE ---------------------------
Only required to be performed in MODE 1.
Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance specific activity::; 1.0 ~Ci/gm. with the Surveillance Frequency Control Program Between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after a THERMAL POWER change of ~ 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period CALLAWAY PLANT 3.4-42 Amendment No. 202
SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.
All SG tubes satisfying the tube repair criteria shall be plugged in accordance with Steam Generator Program.
APPLICABILITY: MODES 1 2, 3, and 4.
ACTIONS
NOTE ----------------------------------------------------------
Separate Condition entry is allowed for each SG tube.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more SG tubes A.1 Verify tube integrity of 7 days satisfying the tube repair the affected tube(s) is criteria and not plugged in maintained until the next accordance with the Steam refueling outage or Generator Program. inspection.
AND A.2 Plug the affected tube(s) Prior to entering in accordance with the MODE 4 following Steam Generator the next refueling Program. outage or SG tu be inspection (continued)
CALLAWAY PLANT 3.4-43 Amendment No. 202 I
SG Tube Integrity 3.4.17 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met.
B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SG tube integrity not maintained.
CALLAWAY PLANT 3.4-44 Amendment No. 202 ,
SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with the Steam In accordance with Generator Program. the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that satisfies the Prior to entering tube repair criteria is plugged in accordance with the MODE 4 following Steam Generator Program. a SG tube inspection CALLAWAY PLANT 3.4-45 Amendment No. 202 I
Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE.
APPLICABILITY: MODES 1 and 2, MODE 3 with RCS pressure > 1000 psig.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One accumulator A.1 Restore boron 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable due to boron concentration to within concentration not within limits.
limits.
B. One accumulator B.1 Restore accumulator to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable for reasons OPERABLE status.
other than Condition A.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A or B AND not met.
C.2 Reduce RCS pressure to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> s 1000 psig.
D. Two or more accumulators D.1 Enter LCO 3.0.3. Immediately inoperable.
CALLAWAY PLANT 3.5-1 Amendment No. 133
Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. In accordance with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each accumulator is I n accordance
~ 6061 gallons and ~ 6655 gallons. with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is In accordance
~ 602 psig and ~ 648 psig. with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.5-2 Amendment No. 202
Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance 2: 2300 ppm and:::; 2500 ppm. with the Surveillance Frequency Control Program AND
NOTE -------
Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after each solution volume increase of 2: 70 gallons that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator In accordance isolation valve operator when RCS pressure is with the
> 1000 psig. Surveillance Frequency Control Program CALLAWAY PLANT 3.5-3 Amendment No. 202
ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.
NOTES -------------------------------------------
- 1. In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to perform pressure isolation valve testing per SR 3.4.14.1.
- 2. Operation in MODE 3 with ECCS pumps made incapable of injecting, pursuant to LCO 3.4.12, "Cold Overpressure Mitigation System," is allowed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or until the temperature of all RCS cold legs exceeds 375°F, whichever comes first.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more trains A.1 Restore train(s) to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. OPERABLE status.
AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.5-4 Amendment No. 202 I
ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position In accordance with power to the valve operator removed. with the Surveillance Number PO§jitioo Functioo Frequency BNHV8813 Open Safety Injection to RWST Control Program Isolation Valve EMHV8802A Closed SI Hot Legs 2 & 3 Isolation Valve EMHV8802B Closed SI Hot Legs 1 & 4 Isolation Valve EMHV8835 Open Safety Injection Cold Leg Isolation Valve EJHV8840 Closed RHRlSI Hot Leg Recirc Isolation Valve EJHV8809A Open RHR to Accum Inject Loops 1 & 2 Isolation Valve EJHV8809B Open RHR to Accum Inject Loops 3 & 4 Isolation Valve SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance automatic valve in the flow path, that is not locked, with the sealed, or otherwise secured in position, is in the Surveillance correct position. Frequency Control Program SR 3.5.2.3 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program (continued)
CALLAWAY PLANT 3.5-5 Amendment No. 202
ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each ECCS automatic valve in the flow path In accordance that is not locked, sealed, or otherwise secured in with the position, actuates to the correct position on an actual Surveillance or simulated actuation signal. Frequency Control Program SR 3.5.2.6 Verify each ECCS pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, In accordance each mechanical position stop is in the correct with the position. Surveillance Valve Number Frequency Control Program EMV0095 EMV0107 EMV0089 EMV0096 EMV0108 EMV0090 EMV0097 EMV0109 EMV0091 EMV0098 EMV0110 EMV0092 SR 3.5.2.8 Verify, by visual inspection, each ECCS train In accordance containment sump suction inlet is not restricted by with the debris and the suction inlet strainers show no Surveillance evidence of structural distress or abnormal corrosion. Frequency Control Program CALLAWAY PLANT 3.5-6 Amendment No. 202
ECCS - Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS - Shutdown LCO 3.5.3 One ECCS train shall be OPERABLE.
NOTE --------------------------------------------
An RHR subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.
APPLICABILITY: MODE 4.
ACTIONS
NOTE ---------------------------------------------------------
LCO 3.0.4.b is not applicable to ECCS centrifugal charging pump subsystem.
COMPLETION CONDITION REQUIRED ACTION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status.
B. Required ECCS Centrifugal B.1 Restore required ECCS 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Charging Pump subsystem Centrifugal Charging inoperable. Pump subsystem to OPERABLE status.
C. Required Action and C.1 Be in MODE 5. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> associated Completion Time of Condition B not met.
CALLAWAY PLANT 3.5-7 Amendment No. 202 I
ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 The following SRs are applicable for all equipment In accordance with required to be OPERABLE: applicable SRs SR 3.5.2.1 SR 3.5.2.7 SR 3.5.2.3 SR 3.5.2.8 SR 3.5.2,4 CALLAWAY PLANT 3.5-8 Amendment No. 202 I
RWST 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST)
LCO 3.5.4 The RWST shall be OPERABLE.
APPLICABILITY: MODES 1,2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RWST boron concentration A.1 Restore RWST to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> not within limits. OPERABLE status.
OR RWST borated water temperature not within limits.
B. RWST inoperable for B.1 Restore RWST to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> reasons other than OPERABLE status.
Condition A.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.5-9 Amendment No. 202 I
RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 --------------------------------- NOTE ---------------------------
Only required to be performed when ambient air temperature is < 3rF or > 100°F.
Verify RWST borated water temperature is ~ 37°F In accordance and s 100°F. with the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is ~ 394,000 In accordance gallons. with the Surveillance Frequency Control Program SR 3.5.4.3 Verify RWST boron concentration is ~ 2350 ppm and In accordance s 2500 ppm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.5-10 Amendment No. 202
Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow LCO 3.5.5 Reactor coolant pump (RCP) seal injection flow shall be within the limits of Figure 3.5.5-1.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Seal injection flow not within A.1 Adjust manual seal 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limit. injection throttle valves such that the RCP seal injection flow is within the limits of Figure 3.5.5-1.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT Amendment No. 202 I
Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 --------------------------------- NOTE --------------------------
Not required to be performed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after the Reactor Coolant System pressure stabilizes at
~ 2215 psig and ~ 2255 psig.
Verify manual seal injection throttle valves are In accordance adjusted to give a flow within the limits of with the Figure 3.5.5-1. Surveillance Frequency Control Program CALLAWAY PLANT 3.5-12 Amendment No. 202
Seal Injection Flow 3.5.5 Delta P from Charging Header to RCS vs. Total Seal Injection Line Flow 210
_2004~~'~~+-'-~{'+'-~'~~~'~""~~"~"'~~~"'~'~'
E!
f,/)
@:. 190
- J 1/1 f 180-t~-~*~
0 f,/)
~ 170
- 160 1~.,,***'t
- *:4"'
.lil&
0 150 ~"~"f"t.,--1
4'\1
..c:
~ 140 Ci 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 Total Seal Injection Line Flow IGPMI Figure 3.5.5-1 (page 1 of 1)
Delta P from Charging Header to RCS VS. Total Seal Injection Line Flow CALLAWAY PLANT Amendment No. 202 ,
- 1 Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.
APPLICABILITY: MODES 1, 2,3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.6-1 Amendment No. 133
Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and leakage In accordance rate testing except for containment air lock testing, in with the accordance with the Containment Leakage Rate Containment Testing Program. Leakage Rate Testing Program SR 3.6.1.2 Verify containment structural integrity in accordance In accordance with the Containment Tendon Surveillance Program. with the Containment Tendon Surveillance Program CALLAWAY PLANT 3.6-2 Amendment No. 133
Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.
APPLICABILITY: MODES 1, 2,3, and 4.
ACTIONS NOTES
- 1. Entry and exit is permissible to perform repairs on the affected air lock components.
- 2. Separate Condition entry is allowed for each air lock.
- 3. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when air lock leakage results in exceeding the overall containment leakage rate.
CONDITION REQUIRED ACTION TIME A. One or more containment NOTES-air locks with one 1. Required Actions A.1, A.2, containment air lock door and A.3 are not applicable if both inoperable. doors in the same air lock are inoperable and Condition C is entered.
- 2. Entry and exit is permissible for 7 days under administrative controls if both air locks are inoperable.
A.1 Verify the OPERABLE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> door is closed in the affected air lock.
AND (continued)
CALLAWAY PLANT 3.6-3 Amendment No. 133
Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. (continued) A.2 Lock the OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> door closed in the affected air lock.
AND A.3 NOTE Air lock doors in high radiation areas may be verified locked closed by administrative means.
Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock.
B. One or more containment NOTES air locks with containment 1. Required Actions B.1, B.2, air lock interlock and B.3 are not applicable if both mechanism inoperable. doors in the same air lock are inoperable and Condition C is entered.
- 2. Entry and exit of containment is permissible under the control of a dedicated individual.
B.1 Verify an OPERABLE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> door is closed in the affected air lock.
AND B.2 Lock an OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> door closed in the affected air lock.
AND (continued)
CALLAWAY PLANT 3.6-4 Amendment No. 133
Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION B. (continued) 8.3 NOTE Air lock doors in high radiation areas may be verified locked closed by administrative means.
Verify an OPERABLE Once per 31 days door is locked closed in the affected air lock.
C. One or more containment C.1 Initiate action to evaluate Immediately air locks inoperable for overall containment reasons other than leakage rate per Condition A or B. LCO 3.6.1.
AND C.2 Verify a door is closed in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the affected air lock.
AND C.3 Restore air lock to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.6-5 Amendment No. 133
Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
NOT ES -------------------------
SR 3.6.2.1 1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.
- 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.
Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rate the Containment Testing Program. Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at a In accordance time. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-6 Amendment No. 202
Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS K IF%9lfU Put I I r .,-
- 1. Penetration flow path(s) except for containment shutdown purge valve flow paths may be unisolated intermittently under administrative controls.
- 2. Separate Condition entry is allowed for each penetration flow path.
- 3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves.
- 4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.
ACTIONS CONDITION REQUIRED ACTION COMPLETION A. NOTE A.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Only applicable to penetration flow path by penetration flow paths with use of at least one two containment isolation closed and de-activated valves. automatic valve, closed manual valve, blind flange, or check valve One or more penetration with flow through the flow paths with one valve secured.
containment isolation valve inoperable except for AND containment purge valve leakage not within limit.
___ ___ ___ ___ ___ ___ ____ ___ ___ ___ ___(continued)
CALLAWAY PLANT 3.6-7 Amendment No. 133
Containment Isolation Valves 3.6.3 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. (continued) A.2 - NOTES
- 1. Isolation devices in high radiation areas may be verified by use of administrative means.
- 2. Isolation devices that are locked, sealed or otherwise secured may be verified by administrative means.
Verify the affected Once per 31 days penetration flow path is for isolation isolated. devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment (continued)
CALLAWAY PLANT 3.6-8 Amendment No. 133
Containment Isolation Valves 3.6.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. NOTE- B.1 Isolate the affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Only applicable to penetration flow path by penetration flow paths with use of at least one two containment isolation closed and de-activated valves. automatic valve, closed manual valve, or blind flange.
One or more penetration flow paths with two containment isolation valves inoperable except for containment purge valve leakage not within limit.
(continued)
CALLAWAY PLANT 3.6-9 Amendment No. 133
Containment Isolation Valves 3.6.3 ACTIONS (continued)
CONDITION REQUIRED ACTION TIME C. N NOTE C.1 Isolate the affected 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Only applicable to penetration flow path by penetration flow paths with use of at least one only one containment closed and de-activated isolation valves and a automatic valve, closed closed system. manual valve, or blind flange.
One or more penetration AND flow paths with one containment isolation valve inoperable. C.2 NOTES
- 1. Isolation devices in high radiation areas may be verified by use of administrative means.
- 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means.
Verify the affected Once per 31 days penetration flow path is isolated.
(continued)
CALLAWAY PLANT 3.6-1 0 Amendment No. 133
Containment Isolation Valves 3.6.3 ACTIONS (continued)
CONDITION C iCOMPLETION REQUIRED ACTION - TIME D. One or more penetration D.A Isolate the affected 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> flow paths with one or penetration flow path by more containment purge use of at least one valves not within leakage closed and de-activated limits. automatic valve or blind flange.
AND D.2 -_ NOTE S
- 1. Isolation devices in high radiation areas may be verified by use of administrative means.
- 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means.
Verify the affected Once per 31 days penetration flow path is for isolation isolated. devices outside containment AND (continued)
CALLAWAY PLANT 3.6-1 1 Amendment No. 133
Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION TIME D. (continued) Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment AND D.3 Perform SR 3.6.3.6 or Once per 92 days SR 3.6.3.7 for the resilient seal purge valves closed to comply with Required Action D.1.
E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.6-12 Amendment No. 133
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment shutdown purge valve is In accordance sealed closed or closed and blind flange installed with the except for one purge valve in a penetration flow path Surveillance while in Condition D of this LCO. Frequency Control Program Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment SR 3.6.3.2 Verify each containment mini-purge valve is closed, In accordance except when the containment mini-purge valves are with the open for pressure control, ALARA or air quality Surveillance considerations for personnel entry, or for Frequency Surveillances that require the valves to be open. Control Program SR 3.6.3.3 --------------------------------- NOTE ---------------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative controls.
Verify each containment isolation manual valve and In accordance blind flange that is located outside containment and with the not locked, sealed, or otherwise secured and required Surveillance to be closed during accident conditions is closed, Frequency except for containment isolation valves that are open Control Program under administrative controls.
(COntinued)
CALLAWAY PLANT 3.6-13 Amendment No. 202
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.3.4 ***.**.************************** NOTE *.***.**********************
Valves and blind flanges in high radiation areas may be verified by use of administrative means.
Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment and not MODE 4 from locked, sealed, or otherwise secured and required to MODE 5 if not be closed during accident conditions is closed, except performed within for containment isolation valves that are open under the previous administrative controls. 92 days SR 3.6.3.5 Verify the isolation time of each automatic power In accordance with operated containment isolation valve is within limits. the Inservice Testing Program SR 3.6.3.6 .**.*..*.************************ NOTE **..*...*.*.***..***.*****.*
Only required to be performed when containment shutdown purge valve blind flanges are installed.
Perform leakage rate testing for containment In accordance shutdown purge valves with resilient seals and with the associated blind flanges. Surveillance Frequency Control Program Following each reinstallation of the blind flange (continUed)
CALLAWAY PLANT 3.6-14 Amendment No. 202
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.3.7 --------------------------------- NOT E ---------------------------
Only required to be performed for the containment shutdown purge valves when associated blind flanges are removed.
Perform leakage rate testing for containment In accordance mini-purge and shutdown purge valves with resilient with the seals. Surveillance Frequency Control Program Within 92 days after opening the valve SR 3.6.3.8 Verify each automatic containment isolation valve that In accordance is not locked, sealed or otherwise secured in position, with the actuates to the isolation position on an actual or Surveillance simulated actuation signal. Frequency Control Program CALLAWAY PLANT 3.6-15 Amendment No. 202
Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be ~ -0.3 psig and ~ + 1.5 psig.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Containment pressure not A.1 Restore containment 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within limits. pressure to within limits.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-16 Amendment No. 202
Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be ~ 120°F.
APPLICABILITY: MODES 1. 2. 3. and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Containment average air A.1 Restore containment 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> temperature not within limit. average air temperature to within limit.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within In accordance limit. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-17 Amendment No. 202
Containment Spray and Cooling Systems 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray and Cooling Systems LCO 3.6.6 Two containment spray trains and two containment cooling trains shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION TIME A. One containment spray A.1 Restore containment 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> train inoperable. spray train to OPERABLE status. AND 10 days from discovery of failure to meet the LCO B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met.
B.2 Be in MODE 5. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> C. One containment cooling C.1 Restore containment 7 days train inoperable. cooling train to OPERABLE status. AND 10 days from discovery of failure to meet the LCO (continued)
CALLAWAY PLANT 3.6-1 8 Amendment No. 133
Containment Spray and Cooling Systems 3.6.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition C not AND met.
D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E. Two containment spray E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> trains inoperable.
AND OR E.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Two containment cooling trains inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance operated, and automatic valve in the flow path that is with the not locked, sealed, or otherwise secured in position is Surveillance in the correct position. Frequency Control Program SR 3.6.6.2 Operate each containment cooling train fan unit for In accordance 2: 15 minutes. with the Surveillance Frequency Control Program CALLAWAY PLANT Amendment No. 202
Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.6.3 Verify each containment cooling train cooling water In accordance flow rate is 2:: 2200 gpm. with the Surveillance Frequency Control Program SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservice the required developed head. Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in the In accordance flow path that is not locked, sealed, or otherwise with the secured in position, actuates to the correct position on Surveillance an actual or simulated actuation signal. Frequency Control Program SR 3.6.6.6 Verify each containment spray pump starts In accordance automatically on an actual or simulated actuation with the signal. Surveillance Frequency Control Program SR 3.6.6.7 Verify each containment cooling train starts In accordance automatically and minimum cooling water flow rate is with the established on an actual or simulated actuation Surveillance signal. Frequency Control Program SR 3.6.6.8 Verify each spray nozzle is unobstructed. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-20 Amendment No. 202
Recirculation Fluid pH Control System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Recirculation Fluid pH Control (RFPC) System LCO 3.6.7 The RFPC System shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RFPC System inoperable. A.1 Restore RFPC System 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify the integrity of the RFPC System. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-21 Amendment No. 202
Recirculation Fluid pH Control System 3.6.7 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.7.2 Verify the RFPC System ensures an equilibrium sump In accordance pH;:: 7.1. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.6-22 Amendment No. 202
MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)
LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS
- ---- NOTE Separate Condition entry is allowed for each MSSV.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam A.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> generators with one MSSV POWER to < 85% RTR inoperable and the Moderator Temperature Coefficient (MTC) zero or negative at all power levels.
B. One or more steam B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> generators with two or more POWER to less than or MSSV's inoperable, equal to the Maximum Allowable % RTP OR specified in Table 3.7.1-1 for the number of One or more steam OPERABLE'MSSVs.
generators with one MSSV inoperable and the MTC AND positive at any power level.
(continued)
CALLAWAY. PLANT 3.7-1 Amendment No. 1-3,136
MSSVs 3.7.1 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. (continued) B.2 N NOTE Only required in Mode 1.
Reduce the Power 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Range Neutron Flux -
High Trip setpoints to less than or equal to the Maximum Allowable %
RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND OR C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> One or more steam generators with 2 4 MSSVs inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 NOTE Only required to be performed in MODES 1 and 2.
Verify each required MSSV lift setpoint perTable In accordance 3.7.1-2 in accordance with the Inservice Testing with the Inservice Program. Following testing, lift setting shall be within Testing Program
+1%.
CALLAWAY PLANT 3.7-2 Amendment No. 133
MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)
OPERABLE Main Steam Safety Valves versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs PER MAXIMUM ALLOWABLE POWER (% RTP)
STEAM GENERATOR 4 <85 3 *45 I 2 <27 CALLAWAY PLANT 3.7-3 Amendment No. 168
MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)
Main Steam Safety Valve Lift Settings LIFT SETTING VALVE NUMBER (psig +3%/-l %)
- 1 #2 #3 #4 ABV0055 ABV0065 ABV0075 ABV0045 1185 ABV0056 ABV0066 ABV0076 ABV0046 1197 ABV0057 ABV0067 ABV0077 ABV0047 1210 ABV0058 ABV0068 ABV0078 ABV0048 1222 ABV0059 ABV0069 ABV0079 ABV0049 1234 CALLAWAY PLANT 3.7-4 Amendment No. 133
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs), Main Steam Isolation Valve Bypass Valves (MSIVBVs), and Main Steam Low Point Drain Isolation Valves (MSLPDIVs)
LCO 3.7.2 The MSIV and its associated actuator trains, the MSIVBV, and the MSLPDIV in each of the four main steam lines shall be OPERABLE.
APPLICABILITY: For the MSIV and its associated actuator trains in each main steam line:
MODE 1, MODES 2 and 3 except when the MSIV is closed and de-activated.
For the MSIVBV in each main steam line:
MODES 1, 2, and 3 except when:
- a. MSIVBV is closed and de-activated, or
- b. MSIVBV is closed and isolated by a closed manual valve, or
- c. MSIVBV is isolated by two closed manual valves.
For the MSLPDIV in each main steam line:
MODES 1, 2, and 3 except when:
- a. MSLPDIV is closed and de-activated, or
- b. MSLPDIV is closed and isolated by a closed manual valve, or
- c. MSLPDIV is isolated by two closed manual valves.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One MSIV actuator train A.1 Restore MSIV actuator 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.
train to OPERABLE status.
J L - -_ _- , _ . . . . . . , . . . - _
(continuea]
CALLAWAY PLANT 3.7-5 Amendment No. 197
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Two MSIV actuator trains B.1 Restore one MSIV 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable for different actuator train to MSIVs when the inoperable OPERABLE status.
actuator trains are not in the same separation group.
C. Two MSIV actuator trains C.1 Restore one MSIV 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> inoperable when the actuator train to inoperable actuator trains OPERABLE status.
are in the same separation group.
D. Two actuator trains for one D.1 Declare the affected Immediately MSIV inoperable. MSIV inoperable.
E. Three or more MSIV E.1 Declare each affected Immediately actuator trains inoperable. MSIV inoperable.
OR Required Action and associated Completion Time of Condition A, B, or C not met.
F. One MSIV inoperable in F.1 Restore MSIV to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> MODE 1. OPERABLE status.
G Required Action and G1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition F not met.
(continued)
CALLAWAY PLANT 3.7-6 Amendment No. 197
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME H -------------- NOTE ------------ H.1 Close or isolate MSIVBV. 7 days Separate Condition entry is allowed for each main AND steam line.
H.2 Verify MSIVBV is closed Once per 7 days One or more MSIVBVs or isolated.
I. -------------- NOTE ------------ 1.1 Close or isolate 7 days Separate Condition entry is MSLPDIV.
allowed for each main steam line. AND One or more MSLPDIVs 1.2 Verify MSLPDIV is Once per 7 days inoperable. closed or isolated.
J. -------------- NOTE ------------ J.1 Close MSIV. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Separate Condition entry is allowed for each main AND steam line.
J.2 Verify MSIV is closed. Once per 7 days One or more MSIVs inoperable in MODE 2 or 3.
K. Required Action and K.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition H, I, or J AND not met.
K.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.7-7 Amendment No. 197
MSIVs, MSIVBVs, and MSLPDIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.7.2.1 Verify isolation time of each MSIV is within limits. In accordance with the Inservice Testing Program SR 3.7.2.2 Verify each MSIV, each MSIVBV, and each MSLPDIV In accordance actuates to the isolation position on an actual or with the simulated actuation signal. Surveillance Frequency Control Program SR 3.7.2.3 Verify isolation time of each MSIVBV and MSLPDIV is In accordance with within limits. the Inservice Testing Program CALLAWAY PLANT 3.7-8 Amendment No. 202
MFIVs, MFRVs, and MFRVBVs 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs), Main Feedwater Regulating Valves (MFRVs),
and Main Feedwater Regulating Valve Bypass Valves (MFRVBVs)
LCO 3.7.3 The MFIV, MFRV, and MFRVBV in each of the four main feedwater lines shall be OPERABLE.
APPLICABILITY: For the MFIV in each main feedwater line:
MODES 1, 2, and 3 except when:
- a. The MFIV is closed and de-activated; or
- b. The MFRV is closed and de-activated or closed and isolated by a closed manual valve; and the MFRVBV is closed and de-activated, or closed and isolated by a closed manual valve, or isolated by two closed manual valves.
For the MFRV in each main feedwater line:
MODES 1, 2, and 3 except when:
- a. The MFIV is closed and de-activated; or
- b. The MFRV is closed and de-activated or closed and isolated by a closed manual valve.
For the MFRVBV in each main feedwater line:
MODES 1, 2, and 3 except when:
- a. The MFIV is closed and de-activated; or
- b. The MFRVBV is closed and de-activated, or closed and isolated by a closed manual valve, or isolated by two closed manual valves.
CALLAWAY PLANT 3.7-9 Amendment No. 198
MFIVs, MFRVs, and MFRVBVs 3.7.3 ACTIONS
NOTE ----------------------------------------------------------
Separate Condition entry is allowed for each main feedwater line.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more MFIVs A.1 Close MFIV. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.
AND A.2 Verify MFIV is closed. Once per 7 days B. One or more MFRVs B.1 Close or isolate MFRV. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.
AND B.2 Verify MFRV is closed or Once per 7 days isolated.
C. One or more MFRVBVs C.1 Close or isolate 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. MFRVBV.
AND C.2 Verify MFRVBV is closed Once per 7 days or isolated.
D. Two valves in the same 0.1 Isolate affected flow 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> flow path inoperable. path.
E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.7-10 Amendment 198
MFIVs, MFRVs, and MFRVBVs 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 --------------------------------- NOT E ---------------------------
Only required to be performed in MODES 1 and 2.
Verify the closure time of each MFRV and MFRVBV is In accordance with within limits. the Inservice Testing Program SR 3.7.3.2 --------------------------------- NOTE ---------------------------
For the MFRVs and MFRVBVs, only required to be performed in MODES 1 and 2.
Verify each MFIV, MFRV and MFRVBV actuates to In accordance the isolation position on an actual or simulated with the actuation signal. Surveillance Frequency Control Program SR 3.7.3.3 Verify the closure time of each MFIV is within limits. In accordance with the Inservice Testing Program CALLAWAY PLANT 3.7-11 Amendment 202
ASDs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Steam Dump Valves (ASDs)
LCO 3.7.4 Four ASD lines shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One required ASD line A.1 Restore required ASD 7 days inoperable for reasons line to OPERABLE other than excessive ASD status.
seat leakage.
B. Two required ASD lines B.1 Restore all but one 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable for reasons required ASD line to other than excessive ASD OPERABLE status.
seat leakage.
C. Three or more required C.1 Restore all but two 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ASD lines inoperable for required ASD lines to reasons other than OPERABLE status.
excessive ASD seat leakage.
(continUed)
CALLAWAY PLANT 3.7-12 Amendment No. 198 I
ASDs 3.7.4 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME D. One or more of the required D.1 Initiate action to close Immediately ASD(s) inoperable because the associated manual of excessive seat leakage. isolation valve(s).
AND D.2 Restore ASD(s) to 30 days OPERABLE status.
E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.7-13 Amendment No. 199
ASDs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 --------------------------------- NOTE ---------------------------
Only required to be performed in MODES 1 and 2.
Verify one complete cycle of each ASD. In accordance with the Inservice Testing Program SR 3.7.4.2 Verify one complete cycle of each ASD manual In accordance with isolation valve. the Inservice Testing Program CALLAWAY PLANT 3.7-14 Amendment No. 198 I
AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Three AFW trains shall be OPERABLE.
APPLICABILITY: MODES 1,2, and 3.
ACTIONS
NOTE ----------------------------------------------------------
LCO 3.0A.b is not applicable when entering MODE 1.
COMPLETION CONDITION REQUIRED ACTION TIME A. One steam supply to A.1 Restore steam supply to 7 days turbine driven AFW pump OPERABLE status.
inoperable. AND 10 days from discovery of failure to meet the LCO B. One ESW supply to turbine B.1 Restore ESW supply to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> driven AFW pump OPERABLE status.
inoperable. AND 10 days from discovery of failure to meet the LCO (continued)
CALLAWAY PLANT 3.7-15 Amendment No. 198 I
AFW System 3.7.5 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. One AFW train inoperable C.1 Restore AFW train to 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />s*
for reasons other than OPERABLE status.
Condition A or B. AND 10 days from discovery of failure to meet the LCO D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for Condition A, B AND or C not met.
OR D.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Two AFW trains inoperable.
E. Three AFW trains E.1 ------------ No-rE ----------
inoperable. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.
Initiate action to restore Immediately one AFW train to OPERABLE status.
- With the exception that the Completion Time associated with the Condition C entry on 2/3/04 for the turbine driven auxiliary feedwater pump has been extended on a one-time only basis to 144 hours0.00167 days <br />0.04 hours <br />2.380952e-4 weeks <br />5.4792e-5 months <br />. At the time a formal cause of the inoperability is determined, Condition D will be entered immediately.
CALLAWAY PLANT 3.7-16 Amendment No. 198 I
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 --------------------------------- NOTE ---------------------------
Only required to be performed for the AFW flow control valves when the system is placed in automatic control or when THERMAL POWER is > 10% RTP.
Verify each AFW manual, power operated, and In accordance automatic valve in each water flow path, and in both with the steam supply flow paths to the steam turbine driven Surveillance pump, that is not locked, sealed, or otherwise secured Frequency in position, is in the correct position. Control Program SR 3.7.5.2 --------------------------------- NOTE ---------------------------
Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after 2 900 psig in the steam generator.
Verify the developed head of each AFW pump at the In accordance with flow test point is greater than or equal to the required the Inservice Test developed head. Program SR 3.7.5.3 Verify each AFW automatic valve that is not locked, In accordance sealed, or otherwise secured in position, actuates to with the the correct position on an actual or simulated Surveillance actuation signal. Frequency Control Program (continued)
CALLAWAY PLANT 3.7-17 Amendment No. 202
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.5.4 --------------------------------- NOTE ---------------------------
Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after 2 900 psig in the steam generator.
Verify each AFW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.5.5 Verify proper alignment of the required AFW flow Prior to entering paths by verifying flow from the condensate storage MODE 2 tank to each steam generator. whenever unit has been in MODE 5 or 6 for> 30 days CALLAWAY PLANT 3.7-18 Amendment No. 202
CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)
LCO 3.7.6 The CST contained water volume shall be 2: 281,000 gal.
APPLICABILITY: MODES 1,2, and 3.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. CST contained water A.1 Verify by administrative 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> volume not within limit. means OPERABILITY of backup water supply. AND AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter A.2 Restore CST contained 7 days water volume to within limit.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.7-19 Amendment No. 198 I
CST 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST contained water volume is In accordance
- . 281,000 gal. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-20 Amendment No. 202
CCW System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Component Cooling Water (CCW) System LCO 3.7.7 Two CCW trains shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One CCW train inoperable. A.1 ------------ NOTE ----------
Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4,"
for residual heat removal loops made inoperable byCCW.
Restore CCW train to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met.
B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.7-21 Amendment No. 198 I
CCWSystem 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 ----------------------------- NOTE -------------------------
Isolation of CCW flow to individual components does not render the CCW System inoperable.
Verify each CCW manual, power operated, and In accordance automatic valve in the flow path servicing safety with the related equipment, that is not locked, sealed, or Surveillance otherwise secured in position, is in the correct Frequency position. Control Program SR 3.7.7.2 Verify each CCW automatic valve in the flow path that In accordance is not locked, sealed, or otherwise secured in with the position, actuates to the correct position on an actual Surveillance or simulated actuation signal. Frequency Control Program SR 3.7.7.3 Verify each CCW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-22 Amendment No. 202
ESW 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Essential Service Water System (ESW)
LCO 3.7.8 Two ESW trains shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One ESW train inoperable. A.1 ------------ NOTE ----------
for emergency diesel generator made inoperable by ESW.
- 2. Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4," for residual heat removal loops made inoperable by ESW.
(continued)
CALLAWAY PLANT 3.7-23 Amendment No. 198 I
ESW 3.7.8 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One ESW train inoperable. A.1 (continued) --------NOTE-------
A one-time Restore ESW train to Completion Time of OPERABLE status. 14 days is allowed to support planned replacement of ESW 'B' train piping prior to April 30, 2009.
72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.7-24 Amendment 198 I
ESW 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 --------------------------------- NOTE ---------------------------
Isolation of ESW flow to individual components does not render the ESW inoperable.
Verify each ESW manual, power operated, and In accordance automatic valve in the flow path servicing safety with the related equipment, that is not locked, sealed, or Surveillance otherwise secured in position, is in the correct Frequency position. Control Program SR 3.7.8.2 Verify each ESW automatic valve in the flow path that In accordance is not locked, sealed, or otherwise secured in with the position, actuates to the correct position on an actual Surveillance or simulated actuation signal. Frequency Control Program SR 3.7.8.3 Verify each ESW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-25 Amendment No. 202
UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)
LCO 3.7.9 The UHS shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One cooling tower train A.1 Restore cooling tower 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. train to OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met.
OR B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> UHS inoperable for reasons other than Condition A.
CALLAWAY PLANT 3.7-26 Amendment No. 198 I
UHS 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILlANCE FREQUENCY SR 3.7.9.1 Verify water level of UHS is~ 834.0 ft mean sea level. In accordance with the Surveillance Frequency Control Program SR 3.7.9.2 Verify average water temperature of UHS is~ 89°F, In accordance with the Surveillance Frequency Control Program SR 3.7.9.3 Operate each cooling tower fan for?: 15 minutes in In accordance both the fast and slow speed. with the Su rveilla nee Frequency Control Program SR 3.7.9.4 Verify each cooling tower fan starts automatically on In accordance an actual or simulated actuation signal. with the Surveillance Frequency Control Program CALlAWAY PLANT 3.7-27 Amendment No. 208
CREVS 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Control Room Emergency Ventilation System (CREVS)
LCO 3.7.10 Two CREVS trains shall be OPERABLE.
I\l 0 TE --------------------------------------------
The control room envelope (CRE) and control building envelope (CBE) boundaries may be opened intermittently under administrative control.
APPLICABILITY: MODES 1, 2, 3, and 4, During movement of irradiated fuel assemblies.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREVS train A.1 Restore CREVS train to 7 days inoperable for reasons other OPERABLE status.
than Condition B.
(continued)
CALLAWAY PLANT 3.7-28 Amendment No. 198 I
CREVS 3.7.10 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. One or more CREVS trains B.1 Initiate action to Immediately inoperable due to an implement mitigating inoperable CRE boundary or actions.
an inoperable CBE boundary in MODE 1,2,3, or4. AND B.2 Verify mitigating actions to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ensure CRE occupant radiological exposure will not exceed limits and CRE occupants are protected from chemical and smoke hazards.
AND B.3 Restore the CRE 90 days boundary and CBE boundary to OPERABLE status.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A or B not met in MODE 1, 2, 3, or4. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)
CALLAWAY PLANT 3.7-29 Amendment No. 198 I
CREVS 3.7.10 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and 0.1 Place OPERABLE Immediately associated Completion CREVS train in CRVIS Time of Condition A not met mode.
during movement of irradiated fuel assemblies.
OR 0.2.1 Suspend CORE Immediately ALTERATIONS.
AND 0.2.2 Suspend movement of Immediately irradiated fuel assemblies.
E. Two CREVS trains E.1 Suspend CORE Immediately inoperable during movement ALTERATIONS.
of irradiated fuel assemblies.
AND OR E.2 Suspend movement of Immediately One or more CREVS trains irradiated fuel assemblies.
inoperable due to an inoperable CRE boundary or an inoperable CBE boundary during movement of irradiated fuel assemblies.
F. Two CREVS trains F.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.
CALLAWAY PLANT 3.7-30 Amendment No. 198 I
CREVS 3.7.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CREVS train pressurization filter unit In accordance for ~ 15 continuous minutes with the heaters with the operating and each CREVS train filtration fiHer unit for Surveillance
~ 15 continuous minutes. Frequency Control Program SR 3.7.10.2 Perform required CREVS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.10.3 Verify each CREVS train actuates on an actual or In accordance simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.10.4 Perform required unfiltered air in leakage testing of the In accordance with CRE and CBE boundaries in accordance with the the Control Room Control Room Envelope Habitability Program. Envelope Habitability Program CALLAWAY PLANT 3.7-31 Amendment No. 209
CRACS 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Control Room Air Conditioning System (CRACS)
LCO 3.7.11 Two CRACS trains shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One CRACS train A.1 Restore CRACS train to 30 days inoperable. OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not met AND in MODE 1,2,3, or4.
B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)
CALLAWAY PLANT 3.7-32 Amendment No. 198 I
CRACS 3.7.11 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Place OPERABLE Immediately associated Completion CRACS train in Time of Condition A not met operation.
in MODE 5 or 6, or during movement of irradiated fuel OR assemblies.
C.2.1 Suspend CORE ALTERATIONS. Immediately AND C.2.2 Suspend movement of Immediately irradiated fuel assemblies.
D. Two CRACS trains 0.1 Suspend CORE Immediately inoperable in MODE 5 or 6, ALTERATIONS.
or during movement of irradiated fuel assemblies.
AND 0.2 Suspend movement of Immediately irradiated fuel assemblies.
E. Two CRACS trains E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or4.
CALLAWAY PLANT 3.7-33 Amendment No. 198 I
CRACS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each CRACS train has the capability to remove In accordance the assumed heat load. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-34 Amendment No. 202
3.7.12 3.7 PLANT SYSTEMS 3.7.12 Not Used.
CALLAWAY PLANT 3.7-35 Amendment No. 198 I
Emergency Exhaust System 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Emergency Exhaust System (EES)
LCO 3.7.13 Two EES trains shall be OPERABLE.
NOTE --------------------------------------------
The auxiliary or fuel building boundary may be opened intermittently under administrative control.
APPLICABILITY: MODES 1, 2, 3, and 4, During movement of irradiated fuel assemblies in the fuel building.
NOTE --------------------------------------------
The SIS mode of operation is required only in MODES 1, 2, 3 and 4. The FBVIS mode of operation is required only during movement of irradiated fuel assemblies in the fuel building.
ACTIONS
NOTE ----------------------------------------------------------
LCO 3.0.3 is not applicable to the FBVIS mode of operation.
COMPLETION CONDITION REQUIRED ACTION TIME A. One EES train inoperable. A.1 Restore EES train to 7 days OPERABLE status.
B. Two EES trains inoperable B.1 Restore auxiliary building 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> due to inoperable auxiliary boundary to OPERABLE building boundary in status.
MODE 1,2,3 or4.
(continued)
CALLAWAY PLANT 3.7-36 Amendment No. 198 I
Emergency Exhaust System 3.7.13 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A or B not AND met in MODE 1, 2, 3, or 4.
C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Two EES trains inoperable in MODE 1,2,3, or4 for reasons other than Condition B.
D. Required Action and 0.1 Place OPERABLE EES Immediately associated Completion Time train in the FBVIS mode.
of Condition A not met during movement of irradiated fuel assemblies in the fuel building.
OR 0.2 Suspend movement of Immediately irradiated fuel assemblies in the fuel building.
E. Two EES trains inoperable E.1 Suspend movement of Immediately during movement of irradiated fuel irradiated fuel assemblies in assemblies in the fuel the fuel building. building.
CALLAWAY PLANT 3.7-37 Amendment No. 198 I
Emergency Exhaust System 3.7.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Operate each EES train for ~ 15 continuous minutes In accordance with the heaters operating. with the Surveillance Frequency Control Program SR 3.7.13.2 Perform required EES filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP}. theVFTP SR 3.7.13.3 Verify each EES train actuates on an actual or In accordance simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.13.4 Verify one EES train can maintain a negative pressure In accordance
~ 0.25 inches water gauge with respect to with the atmospheric pressure in the auxiliary building during Surveillance the SIS mode of operation. Frequency Control Program SR 3.7.13.5 Verify one EES train can maintain a negative pressure In accordance
~ 0.25 inches water gauge with respect to with the atmospheric pressure in the fuel building during the Surveillance FBVIS mode of operation. Frequency Control Program CALLAWAY PLANT Amendment No. 209
3.7.14 3.7 PLANT SYSTEMS 3.7.14 Not Used.
CALLAWAY PLANT 3.7-39 Amendment No. 198 I
Fuel Storage Pool Water Level 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Storage Pool Water Level LCO 3.7.15 The fuel storage pool water level shall be ~ 23 ft over the top of the storage racks.
APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage pool.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Fuel storage pool water A.1 ------------ NOTE ----------
level not within limit. LCO 3.0.3 is not applicable.
Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the fuel storage pool water level is ~ 23 ft In accordance above the storage racks. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-40 Amendment No. 202
Fuel Storage Pool Boron Concentration 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Fuel Storage Pool Boron Concentration LCO 3.7.16 The fuel storage pool boron concentration shall be ~ 2165 ppm.
APPLICABILITY: When fuel assemblies are stored in the fuel storage pool and a fuel storage pool verification has not been performed since the last movement of fuel assemblies in the fuel storage pool.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Fuel storage pool boron ------------------- NOTE ------------------
concentration not within LCO 3.0.3 is not applicable.
limit.
A.1 Suspend movement of Immediately fuel assemblies in the fuel storage pool.
AND A.2.1 Initiate action to restore Immediately fuel storage pool boron concentration to within limit.
OR A.2.2 Verify by administrative Immediately means that a non-Region 1 fuel storage pool verification has been performed since the last movement of fuel assemblies in the fuel storage pool.
CALLAWAY PLANT 3.7-41 Amendment No. 198 I
Fuel Storage Pool Boron Concentration 3.7.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the fuel storage pool boron concentration is In accordance within limit. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-42 Amendment No. 202
Spent Fuel Assembly Storage 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Spent Fuel Assembly Storc:lge LCO 3.7.17 The combination of initial enrichment and burnup of each spent fuel assembly stored in Region 2 or 3 shall be within the Acceptable Domain of Figure 3.7.17-1 or in accordance with Specification 4.3.1.1.
APPLICABILITY: Whenever any fuel assembly is stored in the fuel storage pool.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Requirements of the LCO A.1 ------------ NO-rE ----------
not met. LCO 3.0.3 is not applicable.
Initiate action to move Immediately the noncomplying fuel assembly to Region 1.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify by administrative means the initial enrichment Prior to storing the andburnup of the fuel assembly is in accordance with fuel assembly in Figure 3.7.17-1 or Specification 4.3.1.1. Region 2 or 3 CALLAWAY PLANT 3.7-43 Amendment No. 198 I
Spent Fuel Assembly Storage 3.7.17 55000 50000
/
- J ACe ~EPTAB _E BUR NUP D )MAIN I FOR REGIO~ 2 AN D 3 S ORAGE
~
45000 c,"V
~
0**
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~
/
'-'" 40000 ..
v V
w "':>
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- J (J) 0 35000 / ~
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~
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w w 30000
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/
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/
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..J 25000
/ <)0
~~
/
~~~ V
- J
~
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20000 v h ~/
..J CD
~
w 15000 (J)
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V (;0 /
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..J 10000 w
- J u
5000 V UNAC CEPTAE LE aUF NUP 0 OMAIN FOR ~EGION 2 OR 3 STO ~AGE o I I I I I I I I I I I I 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 FUEL ASSEMBLY INITIAL ENRICHMENT (w/o U-235)
Figure 3.7.17-1 (page 1 of 1)
MINIMUM REQUIRED FUEL ASSEMBLY BURNUP AS A FUNCTION OF INITIAL ENRICHMENT TO PERMIT STORAGE IN REGIONS 2 AND 3 CALLAWAY PLANT 3.7-44 Amendment No. 198 I
Secondary Specific Activity 3.7.18 3.7 PLANT SYSTEMS 3.7.18 Secondary Specific Activity LCO 3.7.18 The specific activity of the secondary coolant shall be 5 0.10 IlCi/gm DOSE EQUIVALENT 1-131.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> limit.
AND A.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.18.1 Verify the specific activity of the secondary coolant is In accordance 50.10 IlCilgm DOSE EQUIVALENT 1-131. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.7-45 Amendment No. 202
SSIVs 3.7.19 3.7 PLANT SYSTEMS 3.7.19 Secondary System Isolation Valves (SSIVs)
LCO 3.7.19 The SSIVs shall be OPERABLE.
NOTE --------------------------------------------
Locked closed manual SSIVs may be opened under administrative controls.
APPLICABILITY: MODES 1, 2, and 3 except for each secondary system flow path when:
- a. At least one of the two associated SSIVs is closed and de-activated; or
- b. At least one of the two associated SSIVs is closed and isolated by a closed manual valve; or
- c. The SSIV flow path is isolated by two closed manual valves, or two closed de-activated automatic valves, or a combination of a closed manual valve and a closed de-activated automatic valve.
ACTIONS
NO-rE ----------------------------------------------------------
Separate Condition entry is allowed for each secondary system flow path.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more SSIVs ------------------- NOTE ------------------
inoperable. Closed or isolated automatic SSIVs may be opened or unisolated under administrative controls.
A.1 Close or isolate SSIV. 7 days AND A.2 Verify SSIV is closed or Once per 7 days isolated.
(continued)
CALLAWAY PLANT 3.7-46 Amendment No. 198 I
SSIVs 3.7.19 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 Verify the isolation time of each automatic SSIV is In accordance with within limits. the Inservice Testing Program SR 3.7.19.2 Verify each automatic SSIV in the flow path actuates In accordance to the isolation position on an actual or simulated with the actuation signal. Surveillance Frequency Control Program CALLAWAY PLANT 3.7-47 Amendment No. 202
AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:
- a. Two qualified circuits between the offsite transmission network and the onsite Class 'I E AC Electrical Power Distribution System; and
- b. Two diesel generators (DGs) capable of supplying the onsite Class 1E power distribution subsystem(s); and
- c. Load Shedder and Emergency Load Sequencer (LSELS) for Train A and Train B.
APPLICAB IL1TY: MODES 1, 2, 3, and 4.
ACTIONS
NOTE ---------------------------------------------------------
LCO 3.0.4.b is not applicable to DGs.
COMPLETION CONDITION REQUIRED ACTION TIME A. One offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. OPERABLE offsite circuit.
Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter AND A.2 ------------ NOTE ----------
In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature.
(continued)
CALLAWAY PLANT 3.8-1 Amendment No. 199
AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One offsite circuit Declare required 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from inoperable. feature(s) with no offsite discovery of no (continued) power available offsite power to one inoperable when its train concurrent redundant required with inoperability of feature(s) is inoperable. redundant required feature(s)
AND A.3 Restore offsite circuit to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
AND 6 days from discovery of failure to meet LCO B. One DG inoperable. B.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the offsite circuit(s).
AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter AND B.2 NOTE -
In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature.
(continued)
CALLAWAY PLANT 3.8-2 Amendment No. 133
AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME B. One DG inoperable. Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from (continued) feature(s) supported by discovery of the inoperable DG Condition B inoperable when its concurrent with required redundant inoperability of feature(s) is inoperable. redundant required feature(s)
AND B.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG is not inoperable due to common cause failure.
OR B.3.2 ------------ NOTE ----------
The required ACTION of B.3.2 is satisfied by the automatic start and sequence loading of the diesel generator.
Perform SR 3.8.1.2 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG.
AND (continued)
CALLAWAY PLANT 3.8-3 Amendment 186
AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME B. One DG inoperable. B.4 Restore DG to ---------NOTE--------
(continued) OPERABLE status. A one-time Completion Time of 14 days is allowed to support planned replacement of ESW 'B' train piping prior to April 30, 2009.
72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 6 days from discovery of failure to meet LCO C. Two offsite circuits C.1 ------------ NO-rE ----------
inoperable. In MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature.
Declare required 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from feature(s) inoperable discovery of when its redundant Condition C required feature(s) is concurrent with inoperable. inoperability of redundant required features AND (continued)
CALLAWAY PLANT 3.8-4 Amendment 199
AC Sources - Operating 3.8.1 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME C. Two offsite circuits C.2 Restore one offsite circuit 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> I to OPERABLE status.
I (continued)
D. One offsite circuit ------------------- NOTE ------------------
inoperable. I Enter applicable Conditions and
, Required Actions of LCO 3.8.9, AND I "Distribution Systems - Operating,"
when Condition D is entered with no One DG inoperable. I AC power source to any train.
! D.1 Restore offsite circuit to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> I OPERABLE status.
OR D.2 Restore DG to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OPERABLE status.
E. Two D~s inoperable. E.1 Restore one DG to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> I OPERABLE status.
F. One required LSELS F.1 Declare the affected DG Immediately inoperable. and offsite circuit inoperable.
AND Restore required LSELS 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> I F.2 to OPERABLE status.
I (Continued)
CALLAWAY PLANT 3.8-5 Amendment 186 I
AC Sources - Operating 3.8.1 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A, B, C, 0, E, AND or F not met.
G.2 Bein MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> H. Three or more AC sources H.1 Enter LCO 3.0.3. Immediately inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE ~REQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance availability for each required offsite circuit. with the Surveillance Frequency Control Program (contlnueo)
CALLAWAY PLANT 3.8-6 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.2 --------------------------- NOTES -------------------------------
- 1. Performance of SR 3.8.1.7 satisfies this SR.
- 2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
- 3. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.
Verify each DG starts from standby conditions and In accordance achieves steady state voltage ~ 3740 V and ~ 4320 V, with the and frequency ~ 58.8 Hz and ~ 61.2 Hz. Surveillance Frequency Control Program CALLAWAY PLANT 3.8-7 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------- NOTES ----------------------------
- 1. DG loadings may include gradual loading as recommended by the manufacturer.
- 2. Momentary transients outside the load range do not invalidate this test.
- 3. This Surveillance shall be conducted on only one DG at a time.
- 4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.
Verify each DG is synchronized and loaded and In accordance operates for;?: 60 minutes at a load;?: 5580 kW and with the
- 6201 kW. Surveillance Frequency Control Program SR 3.8.1.4 Verify each fuel oil transfer pump starts on low level in In accordance the associated day tank standpipe. with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each In accordance day tank. with the Surveillance Frequency
! Control Program SR 3.8.1.6 Verify each fuel oil transfer system operates to In accordance transfer fuel oil from storage tank to the day tank. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-8 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.7 ------------------------------ NOTE ------------------------------
All DG starts may be preceded by an engine prelube period.
Verify each DG starts from standby condition and In accordance achieves in s; 12 seconds, voltage ~ 3740 V and with the s; 4320 V, and frequency ~ 58.8 Hz and s; 61.2 Hz. Surveillance Frequency Control Program SR 3.8.1.8 Not used.
SR 3.8.1.9 Not used.
SR 3.8.1.10 Verify each DG operating at a power factor $ 0.9 and In accordance
~ 0.8 does not trip and voltage is maintained s; 4784 V with the and frequency is maintained s; 65.4 Hz during and Surveillance following a load rejection of ~ 5580 kWand Frequency s; 6201 kW. Control Program (contInued)
CALLAWAY PLANT 3.8-9 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.11 --------------------------- NOTES -------------------------------
- 1. All DG starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Verify on an actual or simulated loss of offsite power In accordance signal: with the Surveillance
- a. De-energization of emergency buses; Frequency Control Program
- b. Load shedding from emergency buses;
- c. DG auto-starts from standby condition and:
- 1. energizes permanently connected loads in s 12 seconds,
- 2. energizes auto-connected shutdown loads through the shutdown load sequencer,
- 3. maintains steady state voltage;;:: 3740 V and s 4320 V,
- 4. maintains steady state frequency
- 58.8 Hz and s 61.2 Hz, and
- 5. supplies permanently connected and auto-connected shutdown loads for
- 5 minutes.
CALLAWAY PLANT 3.8-10 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued)
SURVEILLANCE FREQUENCY SR 3.8.1.12 --------------------------- NOTES -------------------------------
- 1. All DG starts may be preceded by prelube period.
- 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Verify on an actual or simulated safety injection signal In accordance each DG auto-starts from standby condition and: with the Surveillance
- a. In s 12 seconds after auto-start and during Frequency tests, achieves voltage:::>: 3740 V and s 4320 V; Control Program
- b. In s 12 seconds after auto-start and during tests, achieves frequency:::>: 58.8 Hz and s 61.2 Hz;
- c. Operates for:::>: 5 minutes;
- d. Permanently connected loads remain energized from the offsite power system; and
- e. Emergency loads are auto-connected and energized through the LOCA load sequencer from the offsite power system.
CALLAWAY PLANT 3.8-11 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.8.1.13 Verify each DG's automatic trips are bypassed on In accordance actual or simulated loss of voltage signal on the with the emergency bus concurrent with an actual or Surveillance simulated safety injection signal except: Frequency Control Program
- a. Engine overspeed;
- b. Generator differential current;
- c. Low lube oil pressure;
- d. High crankcase pressure;
- e. Start failure relay; and
- f. High jacket coolant temperature.
CALLAWAY PLANT 3.8-12 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.14 --------------------------- NOTE S -------------------------------
- 1. Momentary transients outside the load and power factor ranges do not invalidate this test.
- 2. The DG may be loaded to:2: 5580 kW and
~ 6201 kW for the entire test period if auto connected design loads are less than 6201 kW.
Verify each DG operating at a power factor ~ 0.9 and In accordance
- 2: 0.8 operates for :2: 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:
- with the
- Surveillance
- a. For :2: 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded :2: 6600 kW and i Frequency
~ 6821 kW; and Control Program
- b. For the remaining hours of the test loaded
- 2: 5580 kW and ~ 6201 kW.
SR 3.8.1.15 --------------------------- NOTE S -------------------------------
- 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated :2: 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded :2: 5580 kW and
~ 6201 kW. Momentary transients outside of load range do not invalidate this test.
- 2. All DG starts may be preceded by an engine prelube period.
Verify each DG starts and achieves, in ~ 12 seconds, In accordance voltage :2: 3740 V, and ~ 4320 V and frequency with the
- 2: 58.8 Hz and ~ 61.2 Hz.
- Surveillance Frequency Control Program CALLAWAY PLANT 3.8-13 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.16 ------------------------------ NOT E ------------------------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Verify each DG: In accordance with the
- a. Synchronizes with offsite power source while Surveillance loaded with emergency loads upon a simulated Frequency restoration of offsite power; Control Program
- b. Transfers loads to offsite power source; and
- c. Returns to ready-to-Ioad operation.
SR 3.8.1.17 ------------------------------ NOTE ------------------------------
This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Verify, with a DG operating in test mode and In accordance connected to its bus, an actual or simulated Safety with the Injection signal overrides the test mode by: Surveillance Frequency
- a. Returning DG to ready-to-Ioad operation; and Control Program
- b. Automatically energizing the emergency load from offsite power.
~comlnuea)
CALLAWAY PLANT 3.8-14 Amendment No. 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
NOT E ------------------------------
This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Verify interval between each sequenced load block is In accordance within +/- 10% of design interval for each LOCA and with the shutdown load sequencer. Surveillance Frequency Control Program CALLAWAY PLANT 3.8-15 Amendment 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
NOT ES -------------------------------
- 1. All DG starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Verify on an actual or simulated loss of offsite power In accordance signal in conjunction with an actual or simulated with the Safety Injection signal: Surveillance Frequency
- a. De-energization of emergency buses; Control Program
- b. Load shedding from emergency buses; and
- c. DG auto-starts from standby condition and:
- 1. energizes permanently connected loads in ~ 12 seconds,
- 2. energizes auto-connected emergency loads through LOCA load sequencer,
- 3. achieves steady state voltage ~ 3740 V and 54320 V,
- 4. achieves steady state frequency
~ 58.8 Hz and ~ 61.2 Hz, and
- 5. supplies permanently connected and auto-connected emergency loads for
~ 5 minutes.
CALLAWAY PLANT 3.8-16 Amendment 202
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.20 ------------------------------ NOTE ------------------------------
All DG starts may be preceded by an engine prelube period.
Verify when started simultaneously from standby In accordance condition, each DG achieves, in ~ 12 seconds, with the voltage:2': 3740 V and ~ 4320 V, and frequency Surveillance
- 58.8 Hz and ~ 61.2 Hz. Frequency Control Program SR 3.8.1.21 ------------------------------ NOTE ------------------------------
The continuity check may be excluded from the actuation logic test.
Perform ACTUATION LOGIC TEST for each train of In accordance the load shedder and emergency load sequencer. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-17 Amendment No. 202
AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources - Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:
- a. One qualified circuit between the offsite transmission network and the onsite Class 1E AC electrical power distribution subsystem required by LCO 3.8.10, "Distribution Systems - Shutdown"; and
- b. One diesel generator (DG) capable of supplying one train of the onsite Class 1E AC electrical power distribution subsystems required by LCO 3.8.10; and
- c. The shutdown portion of one Load Shedder and Emergency Load Sequencer (LSELS) associated with the required DC and AC electrical power distribution train.
APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.
ACTIONS
NOT E ----------------------------------------------------------
LCO 3.0.3 is not applicable.
COMPLETION CONDITION REQUIRED ACTION TIME A. One required offsite circuit ------------------- NOTE ------------------
inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.10, with the required train de-energized as a result of Condition A.
A.1 Declare affected required Immediately feature(s) with no offsite power available inoperable.
(continued)
CALLAWAY PLANT 3.8-18 Amendment No. 202 I
AC Sources - Shutdown 3.8.2 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A One required offsite circuit A.2.1 Suspend CORE Immediately inoperable. ALTERATIONS.
(continued)
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.
AND A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore Immediately required offsite power circuit to OPERABLE status.
(continued)
CALLAWAY PLANT 3.8-19 Amendment 202 I
AC Sources - Shutdown 3.8.2 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. One required DG B.1 Suspend CORE Immediately inoperable. ALTERATIONS.
AND B.2 Suspend movement of Immediately irradiated fuel assemblies.
AND B.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.
AND B.4 Initiate action to restore Immediately required DG to OPERABLE status.
C. One required LSELS C.1 Declare the affected DG Immediately (shutdown portion) and offsite circuit inoperable. inoperable.
CALLAWAY PLANT 3.8-20 Amendment No. 202 I
AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 --------------------------------- NOTE --------------------------
The following SRs are not required to be performed:
SR 3.8.1.3, 3.8.1.10, SR 3.8.1.11, SR 3,8.1.14 through SR 3.8.1.16, and SR 3,8.1.18, (Shutdown Load Sequencer only).
For AC sources required to be OPERABLE, the In accordance with following SRs are applicable: applicable SRs SR 3.8.1.1 SR 3.8.1.11 SR 3.8,1.2 SR 3.8.114 SR 3.8.1.3 SR 3,8.1.15 SR 3.8.1.4 SR 3.8.1.16 SR 3.8.1.5 SR 3.8.1.18 (shutdown load SR 3.8.1.6 sequencer only)
SR 3,8.1.7 SR 3.8.1.21 (shutdown load SR 3.8.1.10 sequencer only)
CALLAWAY PLANT 3.8-21 Amendment No. 202 I
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).
APPLICABILITY: When associated DG is required to be OPERABLE.
ACTIONS
NOTE ----------------------------------------------------------
Separate Condition entry is allowed for each DG.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more DGs with fuel A.1 Restore fuel oil level to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> level < 80,900 gal and within limits.
> 69,800 gal in storage tank.
B. One or more DGs with lube B.1 Restore lube oil 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> oil inventory < 750 gal and inventory to within limits.
> 686 gal.
C. One or more DGs with C.1 Restore fuel oil total 7 days stored fuel oil total particulates within limit.
particulates not within limit.
D. One or more DGs with new D.1 Restore stored fuel oil 30 days fuel oil properties not within properties to within limits. limits.
(continued)
CALLAWAY PLANT 3.8-22 Amendment No. 202 I
Diesel Fuel Oil, Lube Oil. and Starting Air 3.8.3 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME One or more DGs with two E.1 Restore two starting air 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> starting air receivers in receivers with pressure service with pressure 2:: 435 psig.
< 435 psig and 2:: 250 psig.
QB One or more DGs with only E.2 Restore one starting air 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> one starting air receiver in receiver with pressure service with pressure 2:: 610 psig.
< 610 psig and 2:: 300 psig.
F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.
Time not met.
QB One or more DGs diesel fuel oil, lube oil, or starting air subsystems not within limits for reasons other than Condition A, B, C, D.
or E.
CALLAWAY PLANT 3.8-23 Amendment No. 202 I
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains ~ 80,900 gal In accordance of fuel. with the Surveillance Frequency Control Program SR 3.8.3.2 Verify lubricating oil inventory is ~ 750 gal. In accordance with the Surveillance Frequency Control Program SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of. the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify pressure in two starting air receivers is ~ 435 In accordance psig or pressure in one starting air receiver is ~ 610 with the psig, for each DG starting air subsystem. Surveillance Frequency Control Program SR 3.8.3.5 Check for and remove accumulated water from each In accordance fuel oil storage tank. with the Surveillance Frequency Control Program SR 3.8.3.6 Not used.
CALLAWAY PLANT 3.8-24 Amendment No. 202
DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Train A and Train B DC electrical power subsystems shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One DC electrical power A.1 Restore DC electrical 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> subsystem inoperable. power subsystem to OPERABLE status.
B. Require Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is ~ 130.2 V on float In accordance charge. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-25 Amendment No. 202
DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.2 Verify no visible corrosion at battery terminals and In accordance connectors. with the Surveillance Frequency Control Program Verify battery connection resistance is ~ 69E-6 ohm for cell to cell connections and ~ 69E-6 ohm for terminal connections.
SR 3.8.4.3 Verify battery cells, cell plates, and racks show no In accordance visual indication of physical damage or abnormal with the deterioration that could degrade battery performance. Surveillance Frequency Control Program SR 3.8.4.4 Remove visible terminal corrosion, verify battery cell In accordance to cell and terminal connections are clean and tight, with the and are coated with anti-corrosion material. Surveillance Frequency Control Program SR 3.8.4.5 Verify battery connection resistance is ~ 69E-6 ohm In accordance for cell to cell connections, and ~ 69E-6 ohm for with the terminal connections. Surveillance Frequency Control Program SR 3.8.4.6 Verify each battery charger supplies c 300 amps at In accordance c 130.2 V for c 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. with the Surveillance Frequency Control Program (contlnueo)
CALLAWAY PLANT 3.8-26 Amendment No. 202
DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.7 ----------------------------- NOTES -----------------------------
- 1. The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7.
- 2. This Surveillance shall not be performed in MODE 1, 2, 3, or4.
Verify battery capacity is adequate to supply, and In accordance maintain in OPERABLE status, the required with the emergency loads for the design duty cycle when Surveillance subjected to a battery service test. Frequency Control Program SR 3.8.4.8 ----------------------------- NOTE -------------------------------
This Surveillance shall not be performed in MODE 1, 2,3, or 4.
Verify battery capacity is ~ 80% of the manufacturer's In accordance rating when subjected to a performance discharge with the test or a modified performance discharge test. Surveillance Frequency Control Program 18 months when battery shows degradation or has reached 85% of expected life CALLAWAY PLANT 3.8-27 Amendment No. 202
DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources - Shutdown LCO 3.8.5 The Train A or Train B DC electrical power subsystem shall be OPERABLE to support one train of the DC electrical power distribution subsystems required by LeO 3.8.10, "Distribution Systems - Shutdown."
APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.
ACTIONS
NOTE ----------------------------------------------------------
LCO 3.0.3 is not applicable.
COMPLETION CONDITION REQUIRED ACTION TIME A. Required DC electrical A.1 Declare affected required Immediately power subsystem feature(s) inoperable.
OR A.2.1 Suspend CORE Immediately ALTERATIONS.
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.
(continued)
CALLAWAY PLANT 3.8-28 Amendment No. 202 I
DC Sources - Shutdown 3.8.5 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Required DC electrical A.2.3 Suspend operations Immediately power subsystem involving positive inoperable. reactivity additions that (continued) could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore Immediately required DC electrical power subsystem to OPERABLE status.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 --------------------------------- NOTE ---------------------------
The following SRs are not required to be performed:
SR 3.8.4.6, SR 3.8.4.7, and SR 3.8.4.8.
For DC sources required to be OPERABLE, the In accordance with following SRs are applicable: applicable SRs SR 3.8.4.1 SR 3.8.4.4 SR 3,8.4,7 SR 3.8.4.2 SR 3.8.4.5 SR 3.8.4.8 SR 3.8.4.3 SR 3.8.4.6 CALLAWAY PLANT 3.8-29 Amendment 202 I
Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for Train A and Train B batteries shall be within the limits of Tabe 3.8.6-1.
APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.
ACTIONS
NOTE ----------------------------------------------------------.
Separate Condition entry is allowed for each battery.
COMPLETION CONDITION REQUIRED ACTION TIME A One or more batteries with A1 Verify pilot cells 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> one or more battery cell electrolyte level and float parameters not within voltage meet Category A or B limits. Table 3.8.6-1 Category C limits.
AND A2 Verify battery cell 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> parameters meet Table 3.8.6-1 Category C AND limits.
Once per 7 days thereafter AND A3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6-1.
(continued)
CALLAWAY PLANT 3.8-30 Amendment No. 202 I
Battery Cell Parameters 3.8.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.
Time of Condition A not met.
One or more batteries with average electrolyte temperature of the representative cells < 60 OF.
One or more batteries with one or more battery cell parameters not within Category C values.
SURVEILLANCE REQUIREMENTS SU RVEI LLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 In accordance Category A limits. with the Surveillance Frequency Control Program (continued)
CALLAWAY PLANT 3.8-31 Amendment No. 202
Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 In accordance Category B limits. with the Surveillance Frequency Control Program Once within 7 days after a battery discharge
< 110 V Once within 7 days after a battery overcharge
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of In accordance representative cells is 2: 60°F. with the Surveillance Frequency Control Program CALLAWAY PLANT Amendment No. 202
Battery Cell Parameters 3.8.6 TABLE 3.8.6-1 (PAGE 1 OF 1)
BATTERY CELL PARAMETERS REQUIREMENTS CATEGORY A: CATEGORYC:
LIMITS FOR EACH CATEGORY B: ALLOWABLE LIMITS PARAMETER DESIGNATED LIMITS FOR EACH FOR EACH PILOT CELL CONNECTED CELL CONNECTED CELL Electrolyte Level > Minimum level > Minimum level Above top of plates, indication mark, and indication mark, and and not overflowing
- <::; 114 inch above :<::; 114 inch above maximum level maximum level indication mark(a) indication mark(a)
Float Voltage ~ 2.13 V ~ 2.13 V > 2.07 V Specific Gravity(b)(c) ~ 1.200 ~ 1.195 Not more than 0.020 below average of all AND connected cells Average of all AND connected cells
> 1.205 Average of all connected cells
~ 1.195 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum during equalizing charges provided it is not overflowing.
(b) Corrected for electrolyte temperature and level. Level correction is not required, however, 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.
CALLAWAY PLANT 3.8-33 Amendment No. 202 I
Inverters - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters - Operating LCO 3.8.7 The required Train A and Train B inverters shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One required inverter A.1 ------------ NOTE ----------
inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any vital bus de-energized.
Restore inverter to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> CALLAWAY PLANT 3.8-34 Amendment No. 202 I
Inverters - Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, and alignment to In accordance required AC vital buses. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.8-35 Amendment No. 202
Inverters - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters - Shutdown LCO 3.8.8 The Train A or Train B inverters shall be OPERABLE to support one train of the onsite Class 1E AC vital bus electrical power distribution subsystems required by LeO 3.8.10, "Distribution Systems - Shutdown."
APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.
ACTIONS
NOTE ----------------------------------------------------------
LCO 3.0.3 is not applicable.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.1 Declare affected required Immediately inverters inoperable. feature(s) inoperable.
OR A.2.1 Suspend CORE Immediately ALTERATIONS.
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies .
( continued)
CALLAWAY PLANT 3.8-36 Amendment No. 202 I
Inverters - Shutdown 3.8.8 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required A.2.3 Suspend operations Immediately inverters inoperable. involving positive (continued) reactivity additions that could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, and alignments to In accordance required AC vital buses. with the Surveillance Frequency Control Program CALLAWAY PLANT Amendment 202
Distribution Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems - Operating LCO 3.8.9 Train A and Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One AC electrical power A.1 Restore AC electrical 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> distribution subsystem power distribution inoperable. subsystem to OPERABLE status.
16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO B. One AC vital bus B.1 Restore AC vital bus 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> subsystem inoperable. subsystem to OPERABLE status.
16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO (continued)
CALLAWAY PLANT 3.8-38 Amendment No. 202 I
Distribution Systems - Operating 3.8.9 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME C. One DC electrical power C.1 Restore DC electrical 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> distribution subsystem power distribution inoperable. subsystem to OPERABLE status.
16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E. Two trains with inoperable E.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.
SURVEILLANCE REQUIREMENTS SU RVEI LLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance required AC, DC, and AC vital bus electrical power with the distribution subsystems. Surveillance Frequency Control Program CALLAWAY PLANT 3.8-39 Amendment No. 202
Distribution Systems - Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems - Shutdown LCO 3.8.10 The necessary portion of the Train A or Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE to support one train of equipment required to be OPERABLE.
APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.
ACTIONS
NOT E ----------------------------------------------------------
LCO 3.0.3 is not applicable.
COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required AC, A.1 Declare associated Immediately DC, or AC vital bus supported required electrical power distribution feature(s) inoperable.
subsystems inoperable.
OR A.2.1 Suspend CORE Immediately ALTERATIONS.
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.
(continued)
CALLAWAY PLANT 3.8-40 Amendment No. 202 I
Distribution Systems - Shutdown 3.8.10 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One or more required AC, A.2.3 Suspend operations Immediately DC, or AC vital bus involving positive electrical power distribution reactivity additions that subsystems inoperable. could result in loss of (continued) required SDM or boron concentration.
A.2.4 Initiate actions to restore Immediately required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.
AND A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to In accordance required AC, DC, and AC vital bus electrical power with the distribution subsystems. Surveillance Frequency Control Program CALLAWAY PLANT 3.8-41 Amendment 202
Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of all filled portions of the Reactor Coolant System and the refueling pool that have direct access to the reactor vessel, shall be maintained sufficient to ensure that the more restrictive of the following reactivity conditions is met:
- a. A kff < 0.95, or
- b. A boron concentration of > 2000 ppm.
APPLICABILITY: MODE 6.
I ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. ALTERATIONS.
AND A.2 Suspend positive Immediately reactivity additions.
AND A.3 Initiate action to restore Immediately boron concentration to within limit.
CALLAWAY PLANT -3.9-1 Amendment No. 164
Boron Concentration 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-2 Amendment No. 202
Unborated Water Source Isolation Valves 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Isolation Valves LCO 3.9.2 Each valve used to isolate unborated water sources shall be secured in the I closed position.
-- ------------ NOTE-------------------------
Unborated water sources may be unisolated under administrative controls for planned boron dilution evolutions. I APPLICABILITY: MODE 6.
ACTIONS
- -------------------- NOTE ------
Separate Condition entry is allowed for each unborated water source isolation valve.
COMPLETION CONDITION REQUIRED ACTION TIME TIME A. NOTE A.1 Suspend CORE Immediately Required Action A.3 must ALTERATIONS.
be completed whenever Condition A is entered. AND One or more valves not A.2 Initiate actions to secure Immediately secured in closed position. valve in closed position.
AND A.3 Perform SR 3.9.1.1. 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> CALLAWAY PLANT 3.9-3 Amendment No. 181
Unborated Water Source Isolation Valves 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water In accordance sources is secured in the closed position. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-4 Amendment No. 202
Nuclear Instrumentation 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Nuclear Instrumentation LCO 3.9.3 Two source range neutron flux monitors shall be OPERABLE.
APPLICABILITY: MODE 6.
ACTIONS COMPLETION TIME CONDITION REQUIRED ACTION TIME A. One required source range A.1 Suspend CORE Immediately neutron flux monitor ALTERATIONS.
ANM A.2 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1.
B. Two required source range B.1 Initiate action to restore Immediately neutron flux monitors one source range inoperable, neutron flux monitor to OPERABLE status.
B.2 Perform SR 3.9.1.1. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CALLAWAY PLANT 3.9-5 Amendment No. 181 I
Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 --------------------------------- NOTE ---------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-6 Amendment No. 202
Containment Penetrations 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Containment Penetrations LCO 3.9.4 The containment penetrations shall be in the following status:
- a. The equipment hatch closed and held in place by four bolts, or if open, capable of being closed;
- b. One door in the emergency air lock and one door in the personnel air lock capable of being closed; and
- c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:
- 1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or
- 2. capable of being closed by an OPERABLE Containment Purge Isolation valve.
-- ---- -- NOTE --- ------ ---
Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.
APPLICABILITY: During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.
ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. One or more containment A.1 Suspend CORE Immediately penetrations not in required ALTERATIONS.
status.
AND A.2 Suspend movement of Immediately irradiated fuel assemblies within containment.
CALLAWAY PLANT 3.9-7 Amendment No. 181 I
Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SLI RVEI LLANCE FREQUENCY SR 3.9.4.1 Verify each required containment penetration is in the In accordance required status. with the Surveillance Frequency Control Program SR 3.9.4.2 --------------------------------- NOTE ---------------------------
Only required for an open equipment hatch.
Verify the capability to install the equipment hatch. In accordance with the Surveillance Frequency Control Program SR 3.9.4.3 Verify each required containment purge isolation In accordance valve actuates to the isolation position on a manual with the actuation signal. Surveillance Frequency Control Program CALLAWAY PLANT 3.9-8 Amendment No. 202
RHR and Coolant Circulation - High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation.
S- --------------- NOTE -----.-.--------.-----......---------
The required RHR loop may be removed from operation for < 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period, provided no operations are permitted that would cause introduction into the Reactor Coolant System, coolant with boron concentration less than that required to meet the minimum required boron concentration of LCO 3.9.1. ---- .. .. -- --. =- . . .. .- .... . ....-
APPLICABILITY: MODE 6 with the water level Ž_23 ft above the top of reactor vessel flange.
ACTIONS COMPLETION REQUIRED ACTION TIME CONDITION TIME A. RHR loop requirements not A.1 Suspend operations that Immediately met. would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1.
AND A.2 Suspend loading Immediately irradiated fuel assemblies in the core.
AND (continued)
CALLAWAY PLANT 3.9-9 Amendment No. 181 I
RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. RHR loop requirements not A.3 Initiate action to satisfy Immediately met. RHR loop requirements.
(continued)
AND AA Close all containment 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetrations providing direct access from containment atmosphere to outside atmosphere.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance reactor coolant at a flow rate of 2 1000 gpm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-10 Amendment 202
RHR and Coolant Circulation - Low Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level LCO 3.9.6 Two RHR loops shallbe OPERABLE, and one RHR loop shall be in operation.
APPLICABILITY: MODE 6 with the water level< 23 ft above the top of reactor vessel flange.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Less than the required A.1 Initiate action to restore Immediately number of RHR loops required RHR loops to OPERABLE. OPERABLE status.
OR A.2 Initiate action to Immediately establish Ž 23 ft of water above the top of reactor vessel flange.
(continued)
CALLAWAY PLANT 3.9-11 Amendment No. 181 I.
RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS (continued)
COMPLETION CONDITION REQUIRED ACTION TIME B. No RHR loop in operation. B.1 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LeO 3.9.1.
AND B.2 Initiate action to restore Immediately one RHR loop to operation.
AND B.3 Close all containment 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetrations providing direct access from containment atmosphere to outside atmosphere.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating In accordance reactor coolant at a flow rate of?: 1000 gpm. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-12 Amendment No. 202
RHR and Coolant Circulation - Low Water Level 3.9.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.9.6.2 Verify correct breaker alignment and indicated power In accordance available to the required RHR pump that is not in with the operation.
CALLAWAY PLANT 3.9-13 Amendment No. 202
Refueling Pool Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Pool Water Level LCO 3.9.7 Refueling pool water level shall be maintained :2 23 ft above the top of reactor vessel flange.
APPLICABILITY: During movement of irradiated fuel assemblies within containment.
ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Refueling pool water level A.1 Suspend movement of Immediately not within limit. irradiated fuel assemblies within containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling pool water level is :2 23 ft above the In accordance top of reactor vessel flange. with the Surveillance Frequency Control Program CALLAWAY PLANT 3.9-14 Amendment No. 202
Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The Callaway Plant site consists of approximately 2,767 acres of rural land 10 miles southeast of the city of Fulton in Callaway County, Missouri, and 80 miles west of the St. Louis metropolitan area.
4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 193 fuel assemblies. Each assembly shall consist of a matrix of Zircalloy or ZIRLO clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (U0 2 ) as fuel material. Limited substitution of fuel rods by zirconium alloy or stainless steel filler rods may be used in accordance with approved applications of fuel rod configurations. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.
4.2.2 Control Rod Assemblies The reactor core shall contain 53 control rod assemblies. The control rod material shall be silver indium cadmium, hafnium metal, or a mixture of both types, as approved by the NRC.
4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:
- a. Fuel assemblies having a maximum nominal U-235 enrichment of 5.0 weight percent; For fuel with enrichments greater than 4.6 nominal weight percent of U-235, the combination of enrichment and integral fuel burnable absorbers shall be sufficient so that the requirements of 4.3.1.1.b are met.
(continued)
CALLAWAY PLANT 4.0-1 Amendment No. 133
Design Features 4.2 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued)
- b. K., . 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the FSAR;
- c. A nominal 8.99 inch center to center distance between fuel assemblies placed in the fuel storage racks;
- d. Partially spent fuel assemblies with a discharge bumup in the "Acceptable Burnup Domain for Region 2 and 3 storage" of Figure 3.7.17-1 may be allowed unrestricted storage in the fuel storage racks, except for the empty cells in the checkerboarding configuration;
- e. Partially spent fuel assemblies with a discharge bumup in the
'Acceptable Bumup Domain for Region 3 Storage" of Figure 3.7.17-1 may be allowed unrestricted storage, except for the empty cells in the checkerboarding configuration, and except in Region 2 locations in a Mixed Zone Three Region configuration in the fuel storage racks; and
- f. New or partially spent fuel assemblies with a discharging burnup in the "Unacceptable Burnup Domain for Region 2 or 3 Storage" of Figure 3.7.17-1 will be stored in Region 1.
4.3.1.2 The new fuel storage racks are designed and shall be maintained with:
- a. Fuel assemblies having a maximum nominal U-235 enrichment of 5.0 weight percent;
- b. ke s 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the FSAR;
- c. k1 f 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in Section 9.1 of the FSAR; and
- d. A nominal 21 inch center to center distance between fuel assemblies placed in the storage racks.
(continued)
CALLAWAY PLANT 4.0-2 Amendment No. 133
Design Features 4.2 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.2 Drainaae The fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 2040 ft.
4.3.3 Capacity The fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 2363 fuel assemblies in the spent fuel pool and no more than 279 assemblies in the cask loading pool.
CALLAWAY PLANT 4.0-3 Amendment No. 133
Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.
The plant manager or his designee shall approve, prior to implementation, each proposed test, experiment or modification to systems or equipment that affect nuclear safety and are not addressed in the Final Safety Analysis Report (FSAR) or Technical Specifications.
5.1.2 The Shift Manager (SM) shall be responsible for the control room command function. During any absence of the SM from the control room while the unit is in MODE 1, 2, 3, or 4, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the SM from the control room while the unit is in MODE 5 or 6, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.
CALLAWAY PLANT 5.0-1 Amendment 173
Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.
- a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications shall be documented in the FSAR;
- b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;
- c. A specified corporate officer shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and
- d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.
5.2.2 Unit Sta The unit staff organization shall include the following:
- a. An equipment operator shall be assigned when fuel is in the reactor and an additional equipment operator shall be assigned when the unit is in MODE 1, 2, 3, or 4.
- b. Shift crew composition may be one less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.f for a period of time not to (continued)
CALLAWAY PLANT 5.0-2 Amendment No. 155
Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.
c A Radiation Protection Department technician shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. in order to provide for unexpected absence, provided immediate action is taken to fill the required position.
- d. Not Used
- e. The operations manager or assistant operations manager shall hold an SRO license.
- f. An individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics. reactor engineering, and plant analysis with regard to the safe operation of the unit. This position shall be assigned when the unit is in MODE 1, 2, 3, or 4, unless the Shift Manager or the Operating Supervisor meet the qualifications as reqUired by the NRC.
CALLAWAY PLANT 5.0-3 Amendment 193
Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI/ANS 3.1-1978, with the following exceptions:
5.3.1.1 Shift Managers, Operating Supervisors, Reactor Operators, and Shift Technical Advisors shall meet or exceed the qualifications of ANSI/ANS 3.1-1981 as endorsed by Reg. Guide 1.8, Revision 2, with the same exceptions as contained in the current revision to the Operator Licensing Examiner Standards, NUREG-1 021, ES-202.
5.3.1.2 The Radiation Protection Manager shall be a supervisor with line responsibility for operational health physics who meets or exceeds the qualifications of USNRC Regulatory Guide 1.8, September 1975, for a Radiation Protection Manager. The Radiation Protection Manager will be designated by the plant manager.
5.3.2 For the purpose of 10 CFR 55.4, a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1, perform the functions described in 10 CFR 50.54(m).
CALLAWAY PLANT 5.0-4 Amendment 173
Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:
- a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;
- b. The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;
, c. Quality assurance for effluent and environmental monitoring;
- d. Not Used; and
- e. All programs specified in Specification 5.5.
CALLAWAY PLANT 5.0-5 Amendment 206
Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.
5.5.1 Offsite Dose Calculation Manual (ODCM1
- a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and
- b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Reports required by Specification 5.6.2 and Specification 5.6.3.
Licensee initiated changes to the ODCM:
- a. Shall be documented and records of reviews performed shall be retained.
This documentation shall contain:
- 1. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and
- 2. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;
- b. Shall become effective after the approval of the plant manager; and
- c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.
(continued)
CALLAWAY PLANT 5.0-6 Amendment No. 155
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the recirculation portion of the Containment Spray, Safety Injection, Chemical and Volume Control, and Residual Heat Removal. The program shall include the following:
- a. Preventive maintenance and periodic visual inspection requirements; and
- b. Integrated leak test requirements for each system at refueling cycle intervals or less.
5.5.3 Not Used 5.5.4 Radioactive Effluent Controls Proqram This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:
- a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM;
- b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to 10 times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001 - 20.2402; (continued)
CALLAWAY PLANT 5.0-7 Amendment No. 144 APR eo 2go1
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)
- c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;
- d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released to unrestricted areas, conforming to 10 CFR 50, Appendix l;
- e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days;
- f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;
- 9. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be in accordance with the following:
- 1. For noble gases: A dose rate of
- 500 mrem/yr to the whole body and a dose rate of
- 3000 mrem/yrto the skin, and
- 2. For lodine-1 31, lodine-1 33, tritium, and for all radionuclides in particulate form with half-lives greater than 8 days: A dose rate of
- 1500 mrem/yrto any organ.
- h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;
- i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-lives > 8 days in gaseous effluents released to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and (continued)
- CALLAWAY PLANT 5.0-8 Amendment No. 133
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)
- . Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190;
- k. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.
5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Section 3.9(N).1.1, "Design Transients", cyclic and transient occurrences to ensure that components are maintained within the design limits.
5.5.6 Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. The program shall include baseline measurements prior to Initial operations. The Tendon Surveillance Program, inspection frequencies, and acceptance criteria shall be in accordance with Section Xl, Subsection IWL of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR 50.55a, except where an exemption or relief has been authorized by the NRC.
The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies.
5.5.7 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendations of Regulatory Position C.4.b of Regulatory Guide 1.14, Revision 1, August 1975.
In lieu of Position C.4.b(1) and C.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle one-half of the outer radius or a surface examination (MT and/or PT) of exposed surfaces of the removed flywheels may be conducted at 20 year intervals.
(continued)
CALLAWAY PLANT 5.0-9 Amendment No. 163
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1,2, and 3 components. The program shall include the following:
- a. Testing frequencies applicable to the ASME Code for Operation and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:
ASME OM Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice activities 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 Biennially or every 2 years At least once per 731 days
- b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities;
- c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and
5.5.9 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:
- a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing (continued)
CALLAWAY PLANT 5.0-10 Amendment 187
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during a SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes.
Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.
- b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.
- 1. Structural integrity performance criterion: All inservice steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cooldown, and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 (3DP) against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.
- 2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG.
Leakage is not to exceed 1 gpm total for all four steam generators.
- 3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."
(continued)
CALLAWAY PLANT 5.0-11 Amendment 1871
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)
- c. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.
- d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.
- 2. Inspect 100% of the tubes at sequential periods of 144,108,72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.
- 3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.
- e. Provisions for monitoring operational primary to secondary LEAKAGE.
(continued)
CALLAWAY PLANT 5.0-12 Amendment 187 I
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation. The program shall include:
- a. Identification of a sampling schedule for the critical variables and control points for these variables;
- b. Identification of the procedures used to measure the values of the critical variables;
- c. Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage;
- d. Procedures for the recording and management of data;
- e. Procedures defining corrective actions for all off control point chemistry conditions; and
- f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.
5.5.11 Ventilation FilterTesting Program (VFTP)
A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Rev. 2, and uses the test procedure guidance in Regulatory Guide 1.52, Revision 2, Positions C.5.a, C.5.c and C.5.d.
- a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < 1.0% when tested at the system flowrate specified below.
ESF Ventilation System Flowrate Control Room Filtration 2000 cfm, +/- 200 cfm Control Room Pressurization 500 cfm, +500, -50 cfm Emergency Exhaust System 9000 cfm, +/- 900 cfm (continued)
CALLAWAY PLANT 5.0-13 Amendment No. 168
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation Filter Testing Program (VFTP) (continued)
- b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < 1.0% when tested at the system flowrate specified below.
ESF Ventilation System Flowrate Control Room Filtration 2000 cfm, +/- 200 cfm Control Room Pressurization 500 cfm, +500, -50 cfm Emergency Exhaust System 9000 cfm, +/- 900 cfm
- c. Demonstrate for each of the ESF systems within 31 days after removal that a laboratory test of a sample of the charcoal adsorber, when obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 301C and the relative humidity specified below.
ESF Ventilation System Penetration RH Control Room Filtration 2.0% 70%
Control Room Pressurization 2.0% 70%
Emergency Exhaust System 2.0% 70%
- d. Demonstrate at least once per 18 months for each of the ESF systems that the pressure drop across the combined HEPA filters and the charcoal adsorbers is less than the value specified below when tested at the system flowrate specified below.
ESF Ventilation System Delta P Flowrate Control Room Filtration 5.4" WG 2000 cfm,
+/- 200 cfm Control Room Pressurization 5.4"WG 500 cfm,
+500,- 50 cfm Emergency Exhaust System 5.4" WG 9000 cfm,
+/- 900 cfm (continued)
CALLAWAY PLANT 5.0-1 4 Amendment No. 168
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation FilterTesting Program (VFTP) (continued)
- e. Demonstrate at least once per 18 months that the heaters for each of the ESF systems dissipate the value specified below when tested in accordance with ANSI 510-1975 and corrected to design nameplate voltage settings.
ESF Ventilation System Wattage Control Room Pressurization 15 +/-2 KW Emergency Exhaust System 37 +/-3 KW The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Gaseous Radwaste System, the quantity of radioactivity contained in gas storage tanks and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks. The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure, Revision 0". The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures, Revision 2".
The program shall include:
- a. The limits for concentrations of hydrogen and oxygen in the Gaseous Radwaste System and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion);
- b. A surveillance program to ensure that the quantity of radioactivity contained in each gas storage tank is less than the amount that would result in a whole body exposure of 2 0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and
- c. A surveillance program to ensure that the quantity of radioactivity contained in the outdoor liquid radwaste tanks listed below that are not (continued)
CALLAWAY PLANT 5.0-1 5 Amendment No. 168
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Explosive Gas and Storage Tank RadioactivitV Monitoring Program (continued) surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste System is less than the quantities determined in accordance with the Standard Review Plan, Section 15.7.3:
- a. Reactor Makeup Water Storage Tank,
- b. Refueling Water Storage Tank,
- c. Condensate Storage Tank, and
- d. Outside temporary tanks, excluding demineralizer vessels and the liner being used to solidify radioactive waste.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.
5.5.13 Diesel Fuel Oil Testing Proqram A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:
- a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:
- 1. an API gravity or an absolute specific gravity within limits,
- 2. a flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and
- 3. a water and sediment content within limits for ASTM 2D fuel oil.
- b. Other properties for ASTM 2D fuel oil are analyzed within 31 days following sampling and addition of new fuel oil to storage tanks; and
- c. Total particulate concentration of the stored fuel oil is < 10 mg/l when tested every 31 days based on applicable ASTM D-2276 standards.
- d. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test frequencies.
(continued)
CALLAWAY PLANT 5.0-1 6 Amendment No. 168
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.14 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.
- a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.
- b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:
- 1. a change in the TS incorporated in the license; or
- 2. a change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.
- c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.
- d. Proposed changes that meet the criteria of Specification 5.5.14b above shall be reviewed and approved by the NRC prior to implementation.
Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 5071 (e).
5.5.15 Safety Function Determination Program (SFDP)
This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:
- a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;
- b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; (continued)
CALLAWAY PLANT 5.0-1 7 Amendment No. 168
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Safety Function Determination Program (SFDP) (continued)
- c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and
- d. Other appropriate limitations and remedial or compensatory actions.
A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:
- a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or
- b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or
- c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.
The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.
5.5.16 Containment Leakage Rate Testing Program
- a. A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September 1995, as modified by the following exceptions:
- 1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by ASME Section Xl Code, Subsection IWL, except where relief has been authorized by the NRC.
(continued)
CALLAWAY PLANT 5.0-1 8 Amendment No. 168
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Containment Leakage Rate Testing Program (continued)
- 2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.
- 3. The unit is excepted from post-modification integrated leakage rate testing requirements associated with steam generator replacement during the Refuel 14 outage (fall of 2005).
- 4. The first Type A test performed after the October 26, 1999 Type A test shall be performed no later than October 25, 2014.
- b. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa' is 48.1 psig.
- c. The maximum allowable containment leakage rate, La' at Pat shall be 0.20% of the containment air weight per day.
- d. Leakage rate acceptance criteria are:
- 1. Containment leakage rate acceptance criterion is : : ; 1.0 La' During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type Band C tests and::::;; 0.75 La for Type A tests;
- 2. Air lock testing acceptance criteria are:
a) Overall air lock leakage rate is:-:;; 0.05 La when tested at
~ Pa ;
b) For each door, leakage rate is : : ; 0.005 La when pressurized to~10psig.
- e. The provisions of Technical Specification SR 3.0.2 do not apply to the test frequencies in the Containment Leakage Rate Testing Program.
- f. The provisions of Technical Specification SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.
(continued)
CALLAWAY PLANT 5.0-19 Amendment 199
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Ventilation System (CREVS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem whole body or its equivalent to any part of the body for the duration of the accident. The program shall include the following elements:
- b. Requirements for maintaining the CRE and CBE boundaries in their design condition, including configuration control and preventive maintenance.
- c. Requirements for (i) determining the unfiltered air inleakage past the CRE and CBE boundaries in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear PO.....0r Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision O.
The following exception is taken to Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0:
- 1. The Tracer Gas Test based on the Brookhaven National Laboratory Atmospheric Tracer Depletion (ATD) Method is used to determine the unfiltered air inleakage past tIle CRE and CBE boundaries. The ATD Method is described in AmerenUE letters dated December 15, 2004 (ULNRC-05104), June 6, 2006 (ULNRC-05298), JUly 16, 2007 (ULNRC-05427), and October 30, 2007 (ULNRC-05448).
- d. Measurement, at designated locations, of the CRE pressure relative to the outside atmosphere during the pressurization mode of operation by one train of the CREVS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.
(continued)
CALLAWAY PLANT 5.0-20 Amendment 190
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.17 Control Room Envelope Habitability Program (continued)
- e. The quantitative limits on unfiltered air inleakage into CRE and CBE.
These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.
The unfiltered air inleakage limit for radiological challenges is the inleakage -now rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air leakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.
- f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE and CBE unfiltered inleakage, and measuring CRE pressure and assessing CRE and CBE as required by paragraphs c and d, respectively.
5.5.18 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.
- a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
- b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04~10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.
- c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
CALLAWAY PLANT 5.0-21 Amendment 202
Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.
5.6.1 Not Used.
5.6.2 Annual Radiological Environmental Operating Report The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 1 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring program for the reporting period.
The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.
The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in a format similar to the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.
5.6.3 Radioactive Effluent Release Report The Radioactive Effluent Release Report covering the operation of the unit during the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.
5.6.4 Not used.
(continued)
CALLAWAY PLANT 5.0-22 Amendment 199
Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR)
- a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:
- 1. Moderator Temperature Coefficient limits in Specification 3.1.3,
- 2. Shutdown Bank Insertion Limit for Specification 3.1.5,
- 3. Control Bank Insertion Limits for Specification 3.1.6,
- 4. Axial Flux Difference Limits for Specification 3.2.3,
- 5. Heat Flux Hot Channel Factor, Fa(Z), FaRTP, K(Z), W(Z) and Fa Penalty Factors for Specification 3.2.1,
- 6. Nuclear Enthalpy Rise Hot Channel Factor F lINH , Ft.H RTP, and Power Factor Multiplier, PF t.H' limits for Specification 3.2.2,
- 7. Shutdown Margin Limits for Specifications 3.1.1, 3.1.4, 3.1.5, 3.1.6, and 3.1.8,
- 8. Reactor Core Safety Limits Figure for Specification 2.1.1,
- 9. Overtemperature CiT and Overpower CiT Setpoint Parameters for Specification 3.3.1, and
- 10. Reactor Coolant System Pressure and Temperature DNB Limits for Specification 3.4.1.
- b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:
- 1. WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY."
- 2. WCAP-10216-P-A, "RELAXATION OF CONSTANT AXIAL OFFSET CONTROL AND FQ SURVEILLANCE TECHNICAL SPECIFICATION."
- 3. WCAP-10266-P-A, "THE 1981 VERSION OF WESTINGHOUSE EVALUATION MODEL USING BASH CODE."
(continued)
CALLAWAY PLANT 5.0-23 Amendment 190 I
Reporting Requirements 5.6 5.6 Reporting Requirements
- 4. WCAP-12610-P-A, "VANTAGE + FUEL ASSEMBLY REFERENCE CORE REPORT."
- 5. WCAP-11397-P-A, "REVISED THERMAL DESIGN PROCEDURE."
- 6. WCAP-14565-P-A, "VIPRE-01 MODELING AND QUALIFICATION FOR PRESSURIZED WATER REACTOR NON-LOCA THERMAL HYDRAULIC SAFETY ANALYSIS."
- 7. WCAP-10851-P-A, "IMPROVED FUEL PERFORMANCE MODELS FOR WESTINGHOUSE FUEL ROD DESIGN AND SAFETY EVALUATIONS."
- 8. WCAP-15063-P-A, "WESTINGHOUSE IMPROVED PERFORMANCE ANALYSIS AND DESIGN MODEL (PAD 4.0)."
- 9. WCAP-8745-P-A, "DESIGN BASES FOR THE THERMAL OVERPOWER DT AND THERMAL OVERTEMPERATURE DT TRIP FUNCTIONS."
- 10. WCAP-10965-P-A, "ANC: A WESTINGHOUSE ADVANCED NODAL COMPUTER CODE."
- 11. WCAP-11596-P-A, "QUALIFICATION OF THE PHOENIX-P/ANC NUCLEAR DESIGN SYSTEM FOR PRESSURIZED WATER REACTOR CORES."
- 12. WCAP-13524-P-A, "APOLLO: A ONE DIMENSIONAL NEUTRON DIFFUSION THEORY PROGRAM."
- c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.
- d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.
(continued)
CALLAWAY PLANT 5.0-24 Amendment 190 I
Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)
- a. RCS pressure and temperature limits for heat up, cooldown, low temperature operation, criticality, hydrostatic testing and PORV lift setting as well as heatup and cooldown rates shall be established and documented in the PTLR for the folloWing:
- 1. Specification 3.4.3, "RCS Pressure and Temperature (PfT) Limits,"
and
- 2. Specification 3.4.12, "Cold Overpressure Mitigation System (COMS)."
- b. The analytical methods used to determine the RCS pressure and temperature and COMS PORV limits shall be those previously reviewed and approved by the NRC, specifically those described in WCAP-14040-NP-A, "Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves".
- c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel f1uence period and for any revision or supplement thereto.
5.6.7 Not used.
5.6.8 PAM Report When a report is required by Condition B or F of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplan ned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.
5.6.9 Not used.
(continued)
CALLAWAY PLANT 5.0-25 Amendment 199
Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.10 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, Steam Generator (SG) Program. The report shall include:
- a. The scope of inspections performed on each SG;
- b. Active degradation mechanisms found;
- c. Nondestructive examination techniques utilized for each degradation mechanism;
- d. Location, orientation (if linear), and measured sizes (if available) of service induced indications;
- e. Number of tubes plugged during the inspection outage for each C'lctive degradation mechanism;
- f. Total number and percentage of tubes plugged to date; and
- g. The results of condition monitoring, including the results of tube pulls and in-situ testing.
CALLAWAY PLANT 5.0-26 Amendment 190 I
High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601 (c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601 (a) and (b) of 10 CFR Part 20:
5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation:
- a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment;
- b. Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.
- c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.
- d. Each individual or group entering such an area shall possess:
- 1. A radiation monitoring device that continuously displays radiation dose rates in the area; or
- 2. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or
- 3. A radiation monitoring device that continuously transmits does rate and cumulative dose rate information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or
- 4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and (continued)
CALLAWAY PLANT 5.0-27 Amendment 190 I
High Radiation Area 5.7 5.7 High Radiation Area 5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation: (continued)
(i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit teleVision, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.
- e. Except for individuals qualified in radiation protection procedures, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them.
5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation. but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation:
- a. Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and, in addition:
- 1. All such door and gate keys shall be maintained under the administrative control of the Shift Manager/Operating Supervisor or Radiation Protection Department Supervision, or his or her designee.
- 2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.
- b. Access to, and activities in, each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.
(Continued)
CALLAWAY PLANT 5.0-28 Amendment 190 I
High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation. but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation: (continued)
- c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.
- d. Each individual or group entering such an area shall possess:
- 1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or
- 2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or
- 3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area, or
- 4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably (C.Jntinued)
CALLAWAY PLANT 5.0-29 Amendment 190 I
High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation. but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation: (continued)
Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.
- e. Except for individual qualified in radiation protection procedures or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them.
- f. Such individual areas that are within a larger area, such as PWR containment, where no enclosure exists for the purpose of locking and where no enclosure can reasonably be constructed around the individual area need not be controlled by a locked door or gate nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible flashing light shall be activated at the area as a warning device.
CALLAWAY PLANT 5.0-30 Amendment 190 I
RCENSE AUTHORITY FILE COPY DO NOT REMOVE D:ssu edt \G 'b 2\t Ppowfy lOo,/d Lic&e)se QPIt-:cO 10-
) l 2g, APPENDIX B TO FACILITY OPERATING LICENSE NO. NPF-30 CALLAWAY PLANT UNIT I UNION ELECTRIC COMPANY DOCKET NO. 50-483 ENVIRONMENTAL PROTECTION.PLAN (NONRADIOLOGICAL)
CALLAWAY PLANT UNIT 1 ENVIRONMENTAL PROTECTION PLAN (NON-RADIOLOGICAL)
TABLE OF CONTENTS Section Page 1.0 Objectives of the Environmental Protection PIlan 1-1 2.0 Environmental Protection Issues . . . . . 2-1 2.1 Aquatic Issues . . . . . . . . . . . . . . 2-1 2.2 Terrestrial Issues . . . . . . . . . . . . .. . 2-1 3.0 Consistency Requirements . . . . . . . . . 3-1 I 3.1 Plant Design and Operation. 3-1 3.2 Reporting Related to the NPDES Permit and State Certification . . . . . . . . . 3-2 3.3 Changes Required for Compliance with Other Environmental Regulations . . . . . . . . . . . . . . 3-3 4.0 Environmental Conditions . . . . . . .. . . ... 4-1 4.1 Unusual or Important Environmental Events . . . : . . 4-1 4.2 Aerial Remote Sensing . . . . . . . . . . 4-1 5.0 Administrative Procedures . . . . . . . . .. .. .
5-1 I 5.1 Review and Audit . . . . . . . . . . . . . . . . . . . 5-1 5.2 Records Retention . . . . . . . . . . . . . . . . . . 5-1 5.3 Changes in Environmental Protection Plan . . . . . . . 5-1 5.4 Plant Reporting Requirements . . . . . . . 5-1 Amendment No. 90 JUL 1 3 1994
1.0 Objectives of the Environmental Protection Plan The Environmental Protection Plan (EPP) is to provide for protection of nonradiological environmental values during operation of Callaway Plant.
The principal objectives of the EPP are as follows:
(1) Verify that the facility is operated in an environmentally acceptable manner, as established by the Final Environmental Statement Operating License Stage NUREG-0813 (FES-OL), and other NRC environmental impact assessments.
(2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.
(3) Keep NRC informed of the environmenal effects of facility operation and of actions taken to control those effects.
Environmental concerns identified in the FES-OL which relate to water quality -
matters are regulated by the NPDES permit issued by the State of Missouri.
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2.0 Environmental Protection Issues In the FES-OL dated January, 1982, the staff considered the environmental impacts associated 'with the operation of Callaway Plant. Certain environ-mental issues were identified which required study or license conditions to resolve environmental concerns and to assure adequate protection of the environmental.
2.1 Aquatic Issues No specific aquatic Issues were raised by the staff in the FES-OL.
2.2 Terrestrial Issues The specific terrestrial issue raised by the staff in the FES-OL is the need to undertake a limited-term terrestrial monitoring program by means of infrared aerial photography with accompanying ground truth aimed at monitoring the impact of cooling tower drift on the local flora. (FES-OL: Section 5.5.1.6) 2-1 Amendment No.9 0 JUL 1.3 1994
3.0 Consistency Requirements 3.1 Plant Design and Operation The licensee may make changes in station design or operation or perform tests or experiments affecting the environment provided such activities do not involve an unreviewed environmental question and do not involve a change in the EPP*. Changes in plant design, operation, performance of tests or experiments which do not affect the environment are not subject to this EPP.
Activities governed by Section 3.3 are not subject to the requirements of this Section.
Before engaging in additional construction or operational activities which may significantly affect the environment, the licensee shall prepare and record an environmental evaluation of such activity. Activities are excluded from this requirement if all measurable nonradiological environmental effects are confined to the on-site areas previously disturbed during site preparation and plant construction. When the evaluation indicates that such activity involves an unreviewed environmental question, the-licensee shall provide a written evaluation of such activity and obtain prior NRC approval. When such activity involves a change in the EPP, such activity and change to the EPP may be implemented only in accordance with an appropriate license amendment as set forth in Section 5.3 of this EPP.
A proposed change, test or experiment shall be deemed to involve an unreviewed environmental question if it concerns: (1) a matter which may result in a significant increase in any adverse environmental impact previously evaluated in the FES-OL as modified by staff's testimony to.the Atomic Safety and Licensing Board, supplements to the FES, environmental impact appraisals, or in any decisions of the Atomic Safety and Licensing Board; or (2) a significant change in effluents or power level [in accordance with 10 CFR Part 51.5(b)(2)]
or (3) a matter not previously reviewed and evaluated in the documents specified in (1) of this Subsection, which may have a significant adverse environmental impact.
- This provision does not relieve the licensee of the requirements of 10 CFR 50.59.
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The licensee shall maintain records of changes in facility design or operation and of tests and experiments carried out pursuant to this Subsection. These records shall include written evaluations which provide bases for the determina-tion that the change, test, or experiment does not involve an unreviewed environmental question or constitute a decrease in the effectiveness of this EPP to meet the objectives specified in Section 1.0. The licensee shall include as part of the Annual Environmental Operating Report (per Subsection 5.4.1) brief descriptions, analyses, interpretations, and evaluations of such changes, tests and experiments.
3.2 Reporting Related to the NPDES Permit and State Certification Changes to, or renewals of, the NPDES Permit or the State certification shall be reported to the NRC within 30 days following the date the change or renewal is approved. If a permit or certification, in part or in its entirety, is appealed and stayed, the NRC shall be notified within 30 days following the date the stay is granted.
The licensee shall notify the NRC of changes to the effective. 'PDES Permit pro-posed by the licensee by providing NRC with a copy of the proposed change at the same time it is submitted to the permitting agency. The licensee shall provide the NRC a copy of the application for renewal of the NPDES Permit at the same time the application is submitted to the permitting agency.
3.3 Changes Required for Compliance with Other Environmental Regulations Changes in plant design or operation and performance of tests or experiments which are required to achieve compliance with other Federal, State, and local environmental regulations are not subject to the requirements of Section 3.1.
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4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates or could result in significant environmental impact casually related to plant operation shall be recorded and reported to the NRC within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> followed by a written report per Subsection 5.4.2. The following are examples: excessive bird impaction events, onsite plant or animal disease outbreaks, mortality or unusual occur-rence of any species protected by the Endangered Species Act of 1973, fish kills, increase in nuisance organisms or conditions, and unanticipated or emergency discharge of waste water or chemical substances.
No routine monitoring programs are required to implement this condition.
4.2 Aerial Remote Sensing Vegetative communities of the site and vicinity within 1 kilometer of the cooling towers in all directions shall be-aerially photographed to detect and -
assess the effect, or lack thereof, as related to cooling tower drift dispersions.
Photography shall be done by aerial overflight during July 15 to September 15.
Monitoring shall include a program of low altitude color infrared photography.
The scale for full coverage shall be adequate to enable identification of vegetation damage over relatively small areas of terrain. Some circumstances may warrant inspection of photographs discerning individual trees. Such scale should be adequate to resolve impacted features.
Photographs shall be compared with baseline data to ascertain changes in vege-tation. Photographic interpretations shall be verified by ground inspection surveys to confirm areas of stress and non-stress. This program shall require aerial photographic monitoring during the first July 15 - September 15 period after the plant has been in operation for one year and the program shall be repeated once the following year and alternate years for three (3) additional periods. A report shall be submitted as part of the annual report following each aerial photographic monitoring period. The report shall contain a de-scription of the program, results, and interpretative analyses of environmental impacts. Results reported shall contain information encompassing but not limited to the following: sampling date; time of day; film types; and one (1) set of resultant color transparencies encompassing an area within approx-imately a one kilometer (1 km) radius of the Unit 1 towers.
4-1
5.0 Administrative Procedures 5.1 Review and Audit The licensee shall provide for review and audit of compliance with the EPP.
The audits shall be conducted independently of the individual or groups responsible for performing the specific activity. A description of the organization structure utilized to achieve the independent review and audit function and results of the audit activities shall be maintained and made available for inspection.
5.2 Records Retention Records and logs relative to the environmental aspects of plant operation shall be made and retained in a manner convenient for review and inspection.
These records and logs shall be made available to NRC on request.
Records of modifications to station structures, systems and components determined to potentially affect the continued protection of the environment -
shall be retained for the life of the station. All other records, data and logs relating to this EPP shall be retained for five years or, where applicable, in accordance with the requirements of other agencies.
5.3 Changes in Environmental Protection Plan Requests for changes in the EPP shall include an assessment of the environmental impact of the proposed change and a supporting justification. Implementation of such changes in the EPP shall not commence prior to NRC approval of the proposed changes in the form of a license amendment incorporating the appropriate revision to the EPP.
5.4 Plant Reporting Requirements 5.4.1 Routine Reports An Annual Environmental Operating Report describing implementation of this EPP for the previous calendar year shall be submitted to the NRC prior to May 1 of each year. The initial report shall be submitted prior to May 1 of the year following issuance of the operating license. The period of the first report shall begin with the date of issuance of the operating license.
5-1
The report shall include summaries and analyses of the results of the environ-mental protection activities required by Subsection 4.2 of this EPP for the report period, including a comparison with related preoperational studies, operational controls (as appropriate), and previous non-radiological environ-mental monitoring reports, and an assessment of the observed impacts of the plant operation on the environment. If harmful effects or evidence of trends toward irreversible damage to the environment are observed, the licensee shall provide a detailed analysis of the data and a proposed course of action to alleviate the problem.
The Annual Environmental Operating Report shall also include:
(1) A list of EPP noncompliances and the corrective actions taken to remedy them.
(2) A list of all changes in station design or operation, tests, and experiments made in accordance with Subsection 3.1 which involved a potentially significant unreviewed environmental question.
(3) A list of nonroutine reports submitted in accordance with Subsection 5.4.2.
\ In the event that some results are not available by the report due date, the report shall be submitted noting and explaining the missing results. The miss-ing results shall be submitted as soon as possible in a supplementary report.
5.4.2 Nonroutine Reports A written report shall be submitted to the NRC within 30 days of occurrence of an unusual or important environmental event (see Section 4.1). The report shall (a) describe, analyze, and evaluate the event, including extent and magnitude of the impact, and plant operating conditions, (b) describe the probable cause of the event, (c) indicate the action taken to correct the reported event, (d) indicate the corrective action taken to preclude'repeti-tion of the event and to prevent similar occurrences involving similar components or systems, and (e) indicate the agencies notified and their preliminary responses.
Events reportable under this subsection which also require reports to other Federal, State or local agencies shall be reported in accordance with those reporting requirements in lieu of the requirements of this Subsection. The NRC shall be provided a copy of-such report at the time it is submitted to the other agency.
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APPENDIX C ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-30 UE shall comply with the following conditions on the schedules noted below:
Amendment Implementation Number Additional Conditions Date 133 This amendment authorizes the The amendment shall relocation of certain Technical be implemented by Specification requirements to April 30, 2000.
licensee-controlled documents.
Implementation of this amendment shall include the relocation of these Technical Specification requirements to the appropriate documents, as described in Table LG of Details Relocated from Current Technical Specifications, Table R of Relocated Current Technical Specifications, and Table LS of Less Restrictive Changes to Current Technical Specifications that are attached to the NRC staff's Safety Evaluation enclosed with this amendment.
133 The schedule for the performance of new The amendment shall and revised Surveillance Requirements be implemented by (SRs) shall be as follows: April 30, 2000.
For SRs that are new in this amendment, the first performance is due at the end of the first surveillance interval that begins on the date of implementation of this amendment.
For SRs that existed prior to this amendment whose intervals of performance are being reduced, the first reduced surveillance interval begins upon completion of the first surveillance performed after implementation of this amendment.
Amendment No. 133 MAY 2 8 1999
-2 Amendment Number Additional Conditions Implem,entation Date 133 For SRs that existed prior to this amendment that The amendment shall have modified acceptance criteria, the first be implemented by performance is due at the end of the first April 30, 2000.
surveillance interval that began on the date the surveillance was last performed prior to the implementation of this amendment.
For SRs that existed prior to this amendment whose intervals of performance are being extended, the first extended surveillance interval begins upon completion of the last surveillance performed prior to implementation of this amendment.
180 Technical Specification (TS) 3.6.7 requires the Prior to MODE 4 Recirculation Fluid pH Control System to be ascending during OPERABLE and Surveillance Requirement (SR) startup from the 3.6.7.2 requires verification that the sump pH be ~ Refuel 15 outage.
7.1. Trisodium phosphate crystalline (TSP-C) will be used for pH control as described in TS Bases 3.6.7. NRC approval is required prior to using a different chemical for pH control.
190 Upon implementation of License Amendment The amendment shall adopting TSTF-448, Revision 3, the determination be implemented within of control room envelope (CRE) and control 120 days from the date building envelope (CBE) boundary unfiltered air of its issuance.
inleakage as required by SR 3.7.10.4, in accordance with TS 5.5.17.c.(i), the assessment of CRE habitability as required by Specification 5.5.17.c.(ii), and the measurement of control room pressure as required by Specification 5.5.17.d, shall be considered met. Following implementation:
(a) The first performance of SR 3.7.10.4, in accordance with Specification 5.5.17.c.(i), shall be within the specified Frequency of 6 years, plus the 18-month allowance of SR 3.0.2, as measured from September 19, 2004, the date of the most recent successful tracer gas test, as stated in the December 15, 2004, letter response to Generic Letter 2003-01, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.
Amendment No. 190
-3 Amendment Number Additional Conditions Implementation Date 190 (b) The first performance of the periodic (cont'd) assessment of CRE habitability, Specification 5.5.17.c.(ii), shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as measured from September 19, 2004, the date of the most recent successful tracer gas test, as stated in the November 16, 2004, letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.
(c) The first performance of the periodic measurement of control room pressure, Specification 5.5.17.d, shall be within 18 months plus the 138 days allowed by SR 3.0.2, as measured from March 16, 2007, the date of the most recent successful pressure measurement test.
Amendment No. 190