ML082600469
| ML082600469 | |
| Person / Time | |
|---|---|
| Site: | Cook  |
| Issue date: | 09/04/2008 |
| From: | Jensen J Indiana Michigan Power Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| AEP:NRC:8381-01 | |
| Download: ML082600469 (29) | |
Text
INDIANA MICHIGAN POWER Indiana Michigan Power Company Nuclear Generation Group One Cook Place Bridgman, Ml 49106 aep.com AEP:NRC:8381-01 10 CFR 50.90 September 4, 2008 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Mail Stop O-P1-17 Washington, DC 20555-0001
SUBJECT:
References:
Donald C. Cook Nuclear Plant Units 1 and 2 Docket Nos. 50-315 and 50-316 Supplement to Emergency Diesel Generator Maximum Steady State Frequency Amendment Request
Nuclear Regulatory Commission (NRC) Document Control Desk, "Technical Specification Change of Diesel Generator Maximum Steady State Frequency,"
AEP:NRC:6381-05, dated June 27, 2007 (ML071910238).
- 2) Letter from J. N. Jensen, I&M, to NRC Document Control Desk, "Response to Revised Request for Additional Information Regarding Proposed Amendment on Emergency Diesel Generator Steady State Frequency (TAC Nos. MD5899 and MD5900)," AEP:NRC:8381, dated April 28, 2008 (ML081280649).
Dear Sir or Madam:
Pursuant to 10 CFR 50.90, Indiana Michigan Power Company (I&M),
the licensee for.
Donald C. Cook Nuclear Plant (CNP) Units 1 and 2, proposes to supplement a previously requested amendment to Facility Operating Licenses DPR-58 and DPR-74.
By Reference 1, I&M proposed to modify the CNP Technical Specifications (TS) to change the emergency diesel generator (EDG) maximum steady state frequency specified in TS 3.8.1, "AC Sources - Operating." By Reference 2, I&M responded to a revised U. S. Nuclear Regulatory Commission (NRC) request for additional information (RAI) regarding the amendment proposed by Reference 1. In that RAI response, I&M stated that it would address one of the NRC questions by submitting a supplement to the original amendment request submitted by Reference 1. I&M stated that the supplement would propose changes to the Surveillance Requirements for TS 3.8.1 such that the minimum EDG voltage required within 10 seconds after the EDG starts would be the same as the minimum EDG voltage required during steady state conditions. In a telephone discussion on r"~~"
0-*
U. S. Nuclear Regulatory Commission AEP:NRC:8381-01 Page 2 August 26, 2008, the NRC Licensing Project Manager was informed that the supplement would be submitted by September 5, 2008.
This letter provides that supplement.
For consistency, this supplement also proposes changes to the minimum EDG frequency required within 10 seconds after the EDG starts and the maximum EDG frequency allowed 2 seconds after rejection of the largest single post-accident load. provides an affirmation statement pertaining to this letter. Enclosure 2 provides I&M's evaluation of the changes proposed by this supplement. Attachments 1 and 2 provide Unit 1 and Unit 2 TS pages marked to show the changes proposed by the original Reference 1 amendment request and the changes proposed by this supplement.
I&M requests approval of the proposed amendment in accordance with the normal NRC review schedule. The proposed changes will be implemented within 45 days of NRC approval.
Copies of this letter and its attachments are being transmitted to the Michigan Public Service Commission and Michigan Department of Environmental Quality, in accordance with the requirements of 10 CFR 50.91.
There are no new or revised commitments in this letter. Should you have any questions, please contact Mr. John A. Zwolinski, Regulatory Affairs Manager, at (269) 466-2478.
Sincerely,
- Jodense eupport Services Vice ýPresident JRW/rdw
Enclosures:
- 1.
Affirmation
- 2.
Indiana Michigan Power Company's Evaluation of Supplemental Changes Attachments:
- 1.
Donald C. Cook Nuclear Plant Unit 1 Technical Specification Pages Marked To Show Proposed Changes
- 2.
Donald C. Cook Nuclear Plant Unit 2 Technical Specification Pages Marked To Show Proposed Changes
U. S. Nuclear Regulatory Commission AEP:NRC:8381-01 Page 3 c:
T. A. Beltz, NRC Washington, DC J. L. Caldwell, NRC Region III K. D. Curry, AEP Ft. Wayne, w/o enclosures/attachments J. T. King, MPSC MDEQ - WHMD/RPS NRC Resident Inspector
t to AEP:NRC:8381-01 AFFIRMATION I, Joseph N. Jensen, being duly sworn, state that I am Site Support Services Vice President of Indiana Michigan Power Company (I&M), that I am authorized to sign and file this request with the Nuclear Regulatory Commission on behalf of I&M, and that the statements made and the matters set forth herein pertaining to I&M are true and correct to the best of my knowledge, information, and belief.
Inin Ycia Power Company
=0.
Jensen Site Support Services Vice President SWORN TO AND SUBSCRIBED BEFORE ME THIS _*
DAY OF rp hcxxb C.2008 MComs Notary Public_ "
My Commission Expires RN D. WINDZErS to AEP:NRC:8381-01 INDIANA MICHIGAN POWER COMPANY'S EVALUATION OF SUPPLEMENTAL CHANGES References for this enclosure are identified in Section 7.
1.0 DESCRIPTION
Indiana Michigan Power Company (I&M) proposes to supplement a previously requested amendment to the Donald C. Cook Nuclear Plant (CNP) facility operating licenses.
By Reference 1, I&M proposed to modify the CNP Technical Specifications (TS) to change the emergency diesel generator (EDG) maximum steady state frequency specified in TS 3.8.1, "AC Sources - Operating." By Reference 2, I&M responded to a revised U. S. Nuclear Regulatory Commission (NRC) request for additional information (RAI) regarding the amendment proposed by Reference 1.
In that RAI response, I&M stated that it would address one of the NRC questions by submitting.a supplement to the original amendment request submitted by Reference 1.
I&M stated that the supplement would propose changes to the Surveillance Requirements (SRs) for TS 3.8.1 such that the minimum EDG voltage required within 10 seconds after the EDG starts would be the same as the minimum EDG voltage required during steady state conditions.
For consistency with these changes, this supplement also proposes changes to the minimum EDG frequency required within 10 seconds after the EDG starts and the maximum EDG frequency allowed 2 seconds after rejection of the largest single post-accident load. This enclosure provides details regarding the supplemental changes and their evaluation.
2.0 PROPOSED CHANGE
In addition to the changes proposed in the original amendment request (Reference 1), I&M proposes to change the minimum voltage and frequency that the EDG must achieve within 10 seconds after starting. The minimum voltage will be changed from 3740 Volts (V) to 3910 V.
The minimum frequency will be changed from 58.8 Hertz (Hz) to 59.4 Hz.
The following TS 3.8.1 SRs are affected:
SR 3.8.1.8.a SR 3.8.1.13.a SR 3.8.1.16.a SR 3.8.1.22 Additionally, I&M proposes to change the maximum EDG frequency allowed to occur within 2 seconds following a rejection of the single largest post-accident load. The maximum frequency will be changed from 61.2 Hz to 60.5 Hz. The affected SR is SR 3.8.1.10.c.
The changes proposed by this supplement indirectly affect TS 3.8.2, "AC Sources - Shutdown,"
since SR 3.8.2.1 requires that SR 3.8.1.8, SR 3.8.1.10, and SR 3.8.1.16 be met.
to AEP:NRC:8381-01 Page 2 Attachments 1 and 2 provide copies of the affected Unit 1 and Unit 2 TS pages marked to show the changes proposed by this supplement and the changes proposed by the original amendment request (Reference 1). The changes proposed by this supplement are indicated by bold font and the changes proposed by the original amendment request are indicated by an underline. Changes to the Bases for TS 3.8.1 reflecting the revised SR requirements will be made in accordance with the CNP TS Bases Control Program.
3.0 BACKGROUND
3.1 System Descriptions As stated in Updated Final Safety Analysis Report (UFSAR) Section 8.4, "Emergency Power System," the emergency power sources for Unit 1 and Unit 2, including the EDGs, are similar and are electrically and physically isolated from one another. Each unit has two full capacity EDGs, each supplying power to two safety-related 4160 V buses.
Each EDG is sized at 3500 kilowatts to assure emergency power is available to operate its associated train of safety equipment assuming a loss-of-power concurrent with a loss-of-coolant accident with or without containment spray.
A loss of offsite power to the 4160 V buses would be sensed by loss of voltage relays. Upon sensing a loss of voltage, relays would automatically start the EDGs, trip the normal feed circuit breakers for the 4160 V buses, trip all motor feeder breakers and 480 V bus transformer feeder breakers on the buses, trip the 600 V bus tie breaker, and trip non-essential 600 V feeder breakers and 480 V bus breakers.
Each EDG would come up to speed and be capable of accepting load within 10 seconds. If either EDG failed to start, the remaining one would be capable of supplying the required engineered safeguard loads. The breakers which connect the EDG output to the 4160/600 V bus system are automatically closed when voltage and speed approach rated values.
A Safety Injection (SI) signal will also start the EDGs.
To avoid overloading of the EDGs, the non-essential loads are shed when the SI occurs and the safety buses are energized from the EDGs.
As stated in the Bases for TS 3.8.1, the minimum steady state EDG voltage of 3910 V specified in the TS 3.8.1 SRs is 94% of the nominal 4160 V output voltage. This value allows for voltage drop to the terminals of 4160 V motors whose minimum operating voltage is specified as 90% or 3740 V. It also allows for voltage drops to motors and other equipment down through the 120 V level where the minimum operating voltage is usually specified as 90% of nameplate rating. An I&M calculation demonstrates that a voltage of 3910 V will provide adequate voltage to the supported safety-related components. The specified minimum steady state frequency of the EDG is 59.4 Hz. This value ensures the engineered safety feature (ESF) pumps can achieve adequate fluid flow to meet their safety and accident mitigation functions. The maximum steady state frequency proposed by Reference 1 is 60.5 Hz. This value will ensure the EDG and the ESF component motors are operated within their design limits.
The 10-second start requirement specified in the TS 3.8.1 SRs supports the assumptions of the design basis loss-of-coolant accident analysis in the UFSAR.
3.2 Reasons for Supplementing the Original Amendment Request As described below, I&M is proposing to change the minimum voltage that must be achieved within 10 seconds following an EDG start to address an NRC concern. This change revises the to AEP:NRC:8381-01 Page 3 EDG transient criterion to match its corresponding steady state criterion.
As also described below, I&M is proposing to change the EDG transient criterion for minimum frequency following an EDG start and the EDG transient criterion for the maximum frequency following a load rejection to match their corresponding steady state criteria.
Change to Minimum EDG Voltage that Must Be Achieved Within 10 Seconds (SR 3.8.1.8.a, SR 3.8.1.13.a, SR 3.8.1.16.a, and SR 3.8.1.22)
By Reference 1, I&M proposed to modify TS to change the EDG maximum steady state frequency specified in the SRs for TS 3.8.1.
By Reference 3, the NRC requested additional information regarding the proposed amendment. In NRC Question 6 of Reference 3, the NRC requested that I&M provide a calculation justifying the TS 3.8.1 SR requirement to achieve a minimum voltage of 3740 V within 10 seconds following an EDG start.
I&M's response to the revised NRC RAI was provided by Reference 2.
In response to NRC Question 6, I&M stated that the original requirement that the CNP EDGs achieve a minimum voltage of 3740 V within 10 seconds was approved by the NRC in 1996 based on an NRC concern that the CNP TS for EDGs were not consistent with the Improved Standard TS. The 3740 V requirement was maintained in the NRC-approved 2005 transition to Improved TS even though the minimum EDG steady state voltage specified in the SRs for TS 3.8.1 was increased to 3910 V. The existing 3740 V is consistent with the value specified in Regulatory Guide 1.9, and is the same as the typical value specified in the NUREG-1431, Improved Standard TS. I&M considers that the existing requirement that the EDG achieve a minimum voltage of 3740 V within 10 seconds provides an acceptable transient criterion for starting the associated safety-related loads.
However, to address the NRC concern and provide consistency between the SRs, I&M stated in Reference 2 that it would submit a supplement to the Reference 1 amendment request. I&M stated that the supplement would propose a TS change to increase the minimum EDG voltage that must be achieved within 10 seconds from 3740 V to 3910 V.
The value of 3910 V corresponds to the minimum EDG steady state voltage specified in the TS 3.8.1 SRs.
Change to Minimum EDG Frequency that Must Be Achieved Within 10 Seconds (SR 3.8.1.8.a, SR 3.8.1.13.a, SR 3.8.1.16.a, and SR 3.8.1.22)
The existing TS requirement that the EDGs achieve a minimum frequency of 58.8 Hz within 10 seconds was originally approved for CNP in 1996 by the same amendment that approved the requirement that the EDGs achieve a minimum voltage of 3740 V within 10 seconds.
Similar to the 3740 voltage criterion, the 58.8 Hz minimum frequency criterion was maintained during the transition to Improved TS even though the minimum steady state frequency specified in the TS 3.8.1 SRs was increased to 59.4 Hz.
Like the voltage requirement, the existing requirement to achieve a minimum frequency of 58.8 Hz within 10 seconds is consistent with the value specified in Regulatory Guide 1.9, and is the same as the typical value specified in the NUREG-1431 Improved Standard TS.
I&M considers that the existing requirement that the EDG achieve a minimum frequency of 58.8 Hz within 10 seconds provides an acceptable transient criterion for starting the associated safety-related loads.
However, since I&M is proposing to change the minimum EDG voltage that must be achieved within 10 seconds to be the same as the minimum EDG voltage that must be achieved during to AEP:NRC:8381-01 Page 4 steady state conditions, I&M is, for consistency, also proposing to change the minimum EDG frequency that must be achieved within 10 seconds to be the same as the minimum. EDG frequency that must be achieved during steady state conditions.
Change to Maximum EDG Frequency Allowed Within 2 Seconds Following Reiection of the Single Largest Post-Accident Load (SR 3.8.1.1O.c)
The criterion for the maximum EDG frequency allowed within 2 seconds following a rejection of the single largest post-accident load and the criteria for the minimum EDG voltage and frequency that must be achieved within 10 seconds following EDG start both apply to transient conditions. Since I&M is proposing to change the minimum EDG voltage and frequency that must be achieved within 10 seconds following an EDG start to be the same as the minimum EDG steady state voltage and frequency limits, I&M is, for consistency, also proposing to change the maximum EDG frequency allowed within 2 seconds following a rejection of the single largest post-accident load to be the same as the proposed maximum EDG steady state frequency limit. I&M has already implemented this change via administrative controls.
4.0 TECHNICAL ANALYSIS
The proposed changes will result in more restrictive values for the minimum voltage and frequency that the EDG must achieve within 10 seconds following EDG start, and for the maximum EDG frequency allowed within 2 seconds following a rejection of the single largest post-accident load. The basis for the more restrictive values is discussed below.
The proposed increase of the minimum voltage that must be achieved within 10 seconds following an EDG start will make the transient criterion the same as the existing minimum voltage that must be achieved under steady state conditions, 3910 V. The 3910 V minimum voltage criterion has been shown by I&M calculations to support all safety-related post-accident loads for the associated EDG.
The proposed increase of the minimum frequency that must be achieved within 10 seconds following an EDG start will make the transient criterion the same as the existing minimum frequency that must be achieved under steady state conditions, 59.4 Hz. The 59.4 Hz minimum frequency criterion has been shown by I&M calculations to support the required ESF pump fluid flows needed to meet their safety and accident mitigation functions.
The proposed decrease of the maximum allowed frequency within 2 seconds following a rejection of the single largest post-accident load will make the transient criterion the same as the maximum steady state frequency criterion proposed by the original Reference 1 amendment request, *60.5 Hz. As detailed in Reference 1, I&M calculations have shown that the _*60.5 Hz criterion will maintain operability of the ESF equipment required for safe shutdown of the facility and the mitigation and control of accident conditions when powered by the EDG.
5.0 REGULATORY SAFETY ANALYSIS 5.1 No Significant Hazards Consideration The following evaluation of significant hazards considerations applies only to the additional Technical Specification changes proposed by this supplement.
The Reference 1 original to AEP:NRC:8381--01 Page 5 amendment request included an evaluation of significant hazards considerations for the original changes.
Indiana Michigan Power Company (I&M) has evaluated whether a significant hazards consideration is involved with the proposed amendment supplement by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:
- 1. Does the proposed change involve a significant increase in the probability of occurrence or consequences of an accident previously evaluated?
Response: No The more restrictive transient voltage and frequency limits ensure that the equipment being powered by the emergency diesel generators (EDGs) will function as designed to mitigate an accident as described in the Update Final Safety Analysis Report (UFSAR). The EDGs and the equipment they power are part of the systems required to mitigate accidents; no accident analyzed in the UFSAR is initiated by mitigation equipment.
Therefore, the proposed change to the transient voltage and frequency limits of the EDGs will not have any impact on the probability of an accident previously evaluated.
Furthermore, other than requiring more restrictive transient voltage and frequency limits on the EDGs, there is no other design or operational change. Therefore, the proposed change does not increase the probability of malfunction of the EDGs or the equipment they power.
The more restrictive EDG transient voltage and frequency limits will ensure that the equipment powered by the EDGs will perform as originally designed and analyzed to mitigate the consequences of any accident described in the UFSAR.
Therefore, the proposed change does not involve a significant increase in the consequences of an accident previously evaluated. in the UFSAR.
Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.
- 2. Does the proposed change create the possibility of a new or different kind of accident from any accident previously evaluated?
Response: No There is no design change associated with the proposed amendment. Making an existing EDG requirement more restrictive alone will not alter plant configuration because no new or different type of equipment will be installed, and because no methods governing plant operation will be changed. The proposed change to the transient voltage and frequency
- limits will not have any effect on the assumptions of accident scenarios previously made in the UFSAR.
Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated.
to AEP:NRC:8381-01 Page 6
- 3. Does the proposed change involve a significant reduction ina margin of safety?
Response: No Despite the proposed change to the EDG transient voltage and frequency limits, the DGs and equipment powered by the EDGs will continue to perform as originally designed, and originally analyzed in the UFSAR. There is no associated change to the methods and assumptions used to analyze EDG performance. The proposed change will maintain the required function of the EDGs and the equipment powered by the EDGs to ensure that operation of structures, systems, or components is as currently set forth in the UFSAR.
Therefore, the proposed change does not involve a significant reduction in the margin of safety.
Based on the above, I&M concludes that the proposed amendment presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified.
5.2 Applicable Regiulatory Requirements/Criteria 10 CFR 50.36(d)(2)(ii), stipulates that a technical specification limiting condition for operation must be established for each item meeting one or more of the following criteria:
- 1. Installed instrumentation that is used to detect, and indicate in the control room, a significant abnormal degradation of the reactor coolant pressure boundary.
- 2. A process variable, design feature, or operating restriction that is an initial condition of a design basis accident or transient analysis that either assumes the failure of, or presents a challenge to the integrity of a fission product barrier.
- 3. A structure, system, or component that is part of the primary success path and which functions or actuates to mitigate a design basis accident or transient that either assumes the failure of or presents a challenge to the integrity of a fission product barrier.
- 4. A structure, system, or component which operating experience or probabilistic risk assessment has shown to be significant to public health and safety.
The change to the diesel generator transient voltage and frequency limits continues to meet this regulation in that it provides assurance that the equipment powered by the diesel generator will be available to actuate to mitigate a design basis accident or transient.
In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Nuclear Regulatory Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health or safety of the public.
to AEP:NRC:8381-01 Page 7
6.0 ENVIRONMENTAL CONSIDERATION
S A review has determined that the proposed amendment would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or SR. However, the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51,22(b); no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.
7.0 REFERENCES
- 1) Letter from J. N. Jensen, I&M, to NRC Document Control Desk, "Technical Specification Change of Diesel Generator Maximum Steady State Frequency," AEP:NRC:6381-05, dated June 27, 2007 (ML071910238).
- 2) Letter from J. N. Jensen, I&M, to NRC Document Control Desk, "Response to Revised Request for Additional Information Regarding Proposed Amendment on Emergency Diesel Generator Steady State Frequency (TAC Nos. MD5899 AND MD5900)," AEP:NRC:8381, dated April 28, 2008 (ML081280649).
- 3) Letter from P. S. Tam, NRC, to M. W. Rencheck, I&M, "D. C. Cook Nuclear Plant, Units 1 and 2 - Request for Additional Information Regarding Proposed Amendment on Emergency Diesel Generator Steady State Frequency (TAC Nos. MD5899 and MD5900)," dated November 28, 2007 (ML073190145).
to AEP:NRC:8381 -01 DONALD C. COOK NUCLEAR PLANT UNIT 1 TECHNICAL SPECIFICATION PAGES MARKED TO SHOW PROPOSED CHANGES 3.8.1-6 3.8.1-8 3.8.1-9 3.8.1-11 3.8.1-12 3.8.1-14 3.8.1-16 3.8.1-18
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS NOTES------------------------------
- 1.
SR 3.8.1.1 through SR 3.8.1.22 are applicable only to the AC electrical power sources for Unit 1.
- 2.
SR 3.8.1.23 is applicable only to the Unit 2 required AC electrical power sources. The Surveillances referenced in SR 3.8.1.23 are the Unit 2 Surveillance Requirements.
SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each offsite circuit.
NOTES---------------
- 1.
All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
- 2.
A modified DG start involving 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 3.8.1.8 must be met.
Verify each DG starts from standby conditions and 31 days achieves steady state voltage _>3910 V and
- <4400 V, and frequency Ž>59.4 Hz and
<6-1,260.5 Hz.
Cook Nuclear Plant Unit 1 3.8.1-6 Amendment No. 2-97, 291
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.8 NOTE All DG starts may be preceded by an engine prelube period.
Verify each DG starts from standby condition and achieves:
- a.
In <10 seconds, voltage _Ž37403910 V and frequency 5_8,59.4 Hz; and
- b.
Steady state voltage _Ž3910 V and *<4400 V, and frequency Ž-59.4 Hz and <64-1260.5 Hz.
184 days SR 3.8.1.9 NOTE ----------------
SR 3.8.1.9.a is only required to be met when the auxiliary source is supplying the electrical power distribution subsystem.
Verify:
- a.
Automatic transfer from the auxiliary source to the preferred offsite circuit; and
- b.
Manual alignment to the alternate offsite circuit.
24 months Cook Nuclear Plant Unit 1 3.8.1-8 Amendment No. 2-97, 291
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.10 NOTES-
- 1.
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 unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
- 2.
If performed with the DG synchronized with offsite power, it shall be performed at a power factor *<0.86. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and:
- a.
Following load rejection, the frequency is
- <64.4 Hz;
- b.
Within 2 seconds following load rejection, the voltage is _>3910 V and <4400 V; and
- c.
Within 2 seconds following load rejection, the frequency is _Ž59.4 Hz and <6-1-4260.5 Hz.
24 months Cook Nuclear Plant Unit 1 3.8.1-9 Amendment No. 287, 291
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 an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power 24 months signal:
- a.
De-energization of emergency buses;
- b.
Load shedding from emergency buses;
- c.
DG auto-starts from standby condition and:
- 1.
Energizes permanently connected loads in _*10 seconds;
- 2.
Energizes auto-connected shutdown loads through time delay relays, where applicable;
- 3.
Maintains steady state voltage.
>_3910 V and _<4400 V;
- 4.
Maintains steady state frequency
Ž_59.4 Hz and _<64-1260.5 Hz; and
- 5.
Supplies permanently connected and auto-connected shutdown loads for
Ž_5 minutes.
Cook Nuclear Plant Unit 1 3.8.1-11 Amendment No. 287, 291
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.13 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 unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and:
- a.
In *<10 seconds achieves voltage
Ž37403910 V and frequency
,58,859.4 Hz;
- b.
Achieves steady state voltage _>3910 V and
- <4400 V and frequency _Ž59.4 Hz and
_<64-1-260.5 Hz;
- c.
Operates for >5 minutes;
- d.
Permanently connected loads remain energized from the offsite power system; and
- e.
Emergency loads are auto-connected through the time delay relays, where applicable, from the offsite power system.
24 months Cook Nuclear Plant Unit 1 3.8.1-12 Amendment No. 287, 291
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.16 NOTES ---------------
- 1.
This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated Ž_2 hours loaded _>3150 kW and
- <3500 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:
- a.
In *<10 seconds, voltage >-37403910 V and frequency _>58 859.4 Hz; and
- b.
Steady state voltage Ž>3910 V and *<4400 V and frequency Ž!59.4 Hz and :564-.,60.5 Hz.
24 months SR 3.8.1.17 NOTE ----------------
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 unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify each DG:
- a.
Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;
- b.
Transfers loads to offsite power source; and
- c.
Returns to ready-to-load operation.
24 months Cook Nuclear Plant Unit 1 3.8.1-14 Amendment No. 2-97, 291
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.19
NOTES---------------
- 1.
All DG starts may be preceded by an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2,3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power 24 months signal in conjunction with an actual or simulated ESF actuation signal:
- a.
De-energization of emergency buses;
- b.
Load shedding from emergency buses; and
- c.
DG auto-starts from standby condition and:
- 1.
Energizes permanently connected loads in *<10 seconds;
- 2.
Energizes auto-connected emergency loads through time delay relays, as applicable;
- 3.
Achieves steady state voltage >3910 V and _<4400 V;
- 4.
Achieves steady state frequency
_59.4 Hz and <6-1-.260.5 Hz; and
- 5.
Supplies permanently connected and auto-cqnnected emergency loads for
Ž>5 minutes.
Cook Nuclear Plant Unit 1 3.8.1-16 Amendment No. 287, 291
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.22
NOTE All DG starts may be preceded by an engine prelube period.
Verify when started simultaneously from standby 10 years condition, each DG achieves, in _<10 seconds, voltage Ž3-7403910 V and frequency
>58,859.4 Hz.
SR 3.8.1.23
NOTES----------------
- 1.
When Unit 2 is in MODE 5 or 6, or moving irradiated fuel assemblies in the containment or auxiliary building, the following Unit 2 SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.10, SR 3.8.1.11, SR 3.8.1.12, SR 3.8.1.15, SR 3.8.1.16, SR 3.8.1.17, and SR 3.8.1.18.
- 2.
Unit 2 SR 3.8.1.9.a is only required to be met when the auxiliary source is supplyingthe required Unit 2 electrical power distribution subsystem.
For required Unit 2 AC sources, the SRs of Unit 2 In accordance Specification 3.8.1, except SR 3.8.1.9.b, with applicable SR 3.8.1.13, SR 3.8.1.14 (ESF actuation signal SRs portion only), SR 3.8.1.19, SR 3.8.1.20, SR 3.8.1.21, and SR 3.8.1.22, are applicable.
Cook Nuclear Plant Unit 1 3.8.1-18 Amendment No. 291 to AEP:NRC:8381-01 DONALD C. COOK NUCLEAR PLANT UNIT 2 TECHNICAL SPECIFICATION PAGES MARKED TO SHOW PROPOSED CHANGES 3.8.1-6 3.8.1-8 3.8.1-9 3.8.1-11 3.8.1-12 3.8.1-14 3.8.1-16 3.8.1-18
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS NOTES.
- 1.
SR 3.8.1.1 through SR 3.8.1.22 are applicable only to the AC electrical power sources for Unit 2.
- 2.
SR 3.8.1.23 is applicable only to the Unit 1 required AC electrical power sources. The Surveillances referenced in SR 3.8.1.23 are the Unit 1 Surveillance Requirements.
SURVEILLANCE "FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each offsite circuit.
NOTES---------------
- 1.
All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
- 2.
A modified DG start involving 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 3.8.1.8 must be met.
Verify each DG starts from standby conditions and 31 days achieves steady state voltage _Ž3910 V and
- _4400 V, and frequency :!59.4 Hz and
_6-1-.260.5 Hz.
Cook Nuclear Plant Unit 2 3.8.1-6 Amendment No. 2-69, 273
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.8 7 ---- NOTE All DG starts may be preceded by an engine prelube period.
Verify each DG starts from standby condition and achieves:
- a.
In *<10 seconds, voltage _Ž37403910 V and frequency _Ž58859.4 Hz; and
- b.
Steady state voltage _Ž3910 V and *<4400 V, and frequency _Ž59.4 Hz and _-64-.260.5 Hz.
184 days SR 3.8.1.9
-NOTE SR 3.8.1.9.a is only required to be met when the auxiliary source is supplying the electrical power distribution subsystem.
Verify:
- a.
Automatic transfer from the auxiliary source to the preferred offsite circuit; and
- b.
Manual alignment to the alternate offsite circuit.
24 months Cook Nuclear Plant Unit 2 3.8.1-8 Amendment No. 269, 273
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.10 NOTES
- 1.
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 unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
- 2.
If performed with the DG synchronized with offsite power, it shall be performed at a power factor *<0.86. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and:
- a.
Following load rejection, the frequency is
- <64.4 Hz;
- b.
Within 2 seconds following load rejection, the voltage is _>3910 V and *<4400 V; and
- c.
Within 2 seconds following load rejection, the frequency is _>59.4 Hz and <6-1-,268.5 Hz.
24 months Cook Nuclear Plant Unit 2 3.8.1-9 Amendment No. 2-&9, 273
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 an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power 24 months signal:
- a.
De-energization of emergency buses;
- b.
Load shedding from emergency buses;
- c.
DG auto-starts from standby condition and:
- 1.
Energizes permanently connected loads in *<10 seconds;
- 2.
Energizes auto-connected shutdown loads through time delay relays, where applicable;
- 3.
Maintains steady state voltage
>_3910 V and _<4400 V;
- 4.
Maintains steady state frequency
_Ž59.4 Hz and _564-.260.5 Hz; and
- 5.
Supplies permanently connected and auto-connected shutdown loads for
_>5 minutes.
I Cook Nuclear Plant Unit 2 3.8.1-11 Amendment No. 269, 273
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY i
SR 3.8.1.13 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 unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and:
- a.
In *<10 seconds achieves voltage
_Ž37403910 V and frequency
Ž58.859.4 Hz;
- b.
Achieves steady state voltage Ž!3910 V and
<4400 V and frequency _Ž59.4 Hz and 5641-.260.5 Hz;
- c.
Operates for Ž_5 minutes;
- d.
Permanently connected loads remain energized from the offsite power system; and
- e.
Emergency loads are auto-connected through the time delay relays, where applicable, from the offsite power system.
24 months Cook Nuclear Plant Unit 2 3.8.1-12 Amendment No. 2-W 273.--
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.16 NOTES ---------------
- 1.
This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated
_>2 hours loaded Ž>3150 kW and
- <3500 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:
- a.
In *<10 seconds, voltage Ž_37403910 V and frequency _58,859.4 Hz; and
- b.
Steady state voltage Ž>3910 V and *<4400 V and frequency _Ž59.4 Hz and _6-1-4260.5 Hz.
24 months SR 3.8.1.17 NOTE ----------------
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 unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify each DG:
- a.
Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;
- b.
Transfers loads to offsite power source; and
- c.
Returns to ready-to-load operation.
24 months Cook Nuclear Plant Unit 2 33.8.1-14 Amendment No. 2-69, 273
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.19
NOTES---------------
- 1.
All DG starts may be preceded by an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power 24 months signal in conjunction with an actual or simulated ESF actuation signal:
- a.
De-energization of emergency buses;
- b.
Load shedding from emergency buses; and
- c.
DG auto-starts from standby condition and:
- 1.
Energizes permanently connected loads in *<10 seconds;
- 2.
Energizes auto-connected emergency loads through time delay relays, as applicable;
- 3.
Achieves steady state voltage _3910 V and *<4400 V;
- 4.
Achieves steady state frequency
_Ž59.4 Hz and _<64-1260.5 Hz; and
- 5.
Supplies permanently connected and auto-connected emergency loads for
_Ž5 minutes.
-Cook Nuclear Plant Unit 2 3.8.1-16 Amendment No. 2-69, 273
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY
-I.
SR 3.8.1.22 NOTE All DG starts may be preceded by an engine prelube period.
Verify when started simultaneously from standby condition, each DG achieves, in <10 seconds, voltage >37403910 V and frequency
>_58.859.4 Hz.
10 years SR 3.8.1.23 NOTES ----------------
- 1.
When Unit 1 is in MODE 5 or 6, or moving irradiated fuel assemblies in the containment or auxiliary building, the following Unit 1 SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.10, SR 3.8.1.11, SR 3.8.1.12, SR 3.8.1.15, SR 3.8.1.16, SR 3.8.1.17, and SR 3.8.1.18.
- 2.
Unit 1 SR 3.8.1.9.a is only required to be met when the auxiliary source is supplying the required Unit 1 electrical power distribution subsystem.
For required Unit 1 AC sources, the SRs of Unit 1 Specification 3.8.1, except SR 3.8.1.9.b, SR 3.8.1.13, SR 3.8.1.14 (ESF actuation signal portion only), SR 3.8.1.19, SR 3.8.1.20, SR 3.8.1.21, and SR 3.8.1.22, are applicable.
In accordance with applicable SRs Cook Nuclear Plant Unit 2 3.8.1-18 Amendment No. 273