Text

Enclosure (2 of 4), Q&A to Attachment 1, Volume 13 (Section 3.8)
	ML102371290
Person / Time
Site:	Kewaunee
Issue date:	08/18/2010
From:	; Dominion Energy Kewaunee
To:	; Office of Nuclear Reactor Regulation
References
	10-457, TAC ME2139
	Download: ML102371290 (48)
	v • d • e

Kewaunee ITS Conversion Database Page 1 of 2 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 1 of 48 ITS NRC Questions Id 1261 NRC Question GMW-005 Number Category Technical ITS Section 3.8 ITS Number 3.8.1 DOC Number JFD 10 Number JFD Bases Number Page 41 of 289 Number(s)

NRC Reviewer Rob Elliott Supervisor Technical Add Name Branch POC Conf Call N

Requested NRC Question Proposed Deletion of SR 3.8.1.20 (Simultaneous Start of EDGs),

Attachment 1, Volume 13, Rev. 0, Page 41 of 289 Regarding the proposed KPS ITS deletion of ISTS SR 3.8.1.20, KPS JFD #10 states: ISTS SR 3.8.1.20 is not included in the Kewaunee ITS. This SR is intended to periodically verify acceptable electrical and physical independence of the DGs and associated electrical distribution systems. Adequate independence (both electrical and physical) of the DGs and associated electrical distribution systems was a requirement (and has been established in) the original plant design. Furthermore, existing maintenance practices and configuration control practices are judged to be sufficient to ensure continued acceptable separation and independence. Thus, there is no need to periodically perform this SR to demonstrate continued acceptable independence or simultaneous start capability.

Explain how the above maintenance and configuration control practices verify acceptable electrical and physical independence of the DGs and associated electrical distribution eliminates the need to periodically start and run(unloaded) redundant units simultaneously, to identify potential common cause failure modes that may be undetected in single diesel-generator tests, as required by 10 CFR 50.36(c)(3), Surveillance requirements.

Attach File 1

Attach File 2

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 1 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1261 06/03/2010

Kewaunee ITS Conversion Database Page 2 of 2 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 2 of 48 Issue Date 12/7/2009 Added By Gerald Waig Date Modified Modified By Date Added 12/7/2009 11:24 AM Notification NRC/LICENSEE Supervision Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 2 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1261 06/03/2010

Kewaunee ITS Conversion Database Page 1 of 2 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 3 of 48 Licensee Response/NRC Response/NRC Question Closure Id 1501 NRC Question GMW-005 Number Select Licensee Response Application

Response

1/5/2010 1:10 PM Date/Time Closure Statement Response Kewaunee Power Station (KPS) is not deleting the test required by ISTS SR Statement 3.8.1.20, a simultaneous EDG start test. The KPS current Technical Specifications (CTS) do not require this test, nor has this test been performed during the commercial operation of KPS. Thus, KPS has decided not to adopt this more restrictive test requirement as part of the ITS amendment request. As stated in both the UFSAR and the ITS Bases, the two EDGs are designed to be independent of one another. ISTS SR 3.8.1.20 is simply verifying that nothing has modified the independence of the EDGs. However, as stated in the Justification for Deviation (JFD) 10, KPS maintenance practices and configuration control requirements ensure that starting independence of the two EDGs is not lost. The KPS plant modification procedure (KW-PROC-ADM-CM-AA-DDC-201, Design Changes) requires a 10 CFR 50.59 review for any modifications that could impact safety related equipment. Since the EDGs are safety related, this review would be required. The review would ensure that the independence of the EDGs is not compromised due to a plant modification. This review is performed by at least one individual and second checked by another individual, both of whom are qualified in 10 CFR 50.59 reviews.

Furthermore, any required 10 CFR 50.59 evaluation must be approved by the Facility Safety Review Committee (FSRC). Therefore, it is the KPS position that this ISTS SR is not required to ensure independence of the EDGs is maintained.

Furthermore, KPS notes that two of the more recently approved ITS conversions, Monticello Nuclear Power Plant and Davis-Besse, also choose not to include this SR in their ITS amendment (it was not in their CTS),

justified not adopting the SR using a similar JFD, and this was accepted by the NRC. For each of the two plants, the docketed CTS Markup, ISTS Markup, and JFD of the ITS submittal, as well as the NRC-approved ITS amendment pages are included for information as an attachment.

Question Closure Date Attachment 1

Attachment 2

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 3 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1501 06/03/2010

Kewaunee ITS Conversion Database Page 2 of 2 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 4 of 48 Notification NRC/LICENSEE Supervision Jerry Jones Bryan Kays Ray Schiele Gerald Waig Added By Robert Hanley Date Added 1/5/2010 1:13 PM Modified By Date Modified Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 4 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1501 06/03/2010

Kewaunee ITS Conversion Database Page 1 of 1 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 5 of 48 Licensee Response/NRC Response/NRC Question Closure Id 1511 NRC Question Number GMW-005 Select Application Licensee Response Response Date/Time 1/5/2010 2:45 PM Closure Statement Response Statement Here are the attachments for GMW-005.

Question Closure Date Attachment 1 GMW-005 Davis Besse info.pdf (3MB)

Attachment 2 GMW-005 Monti info.pdf (310KB)

Notification NRC/LICENSEE Supervision Jerry Jones Bryan Kays Ray Schiele Gerald Waig Added By Robert Hanley Date Added 1/5/2010 2:54 PM Modified By Date Modified Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 5 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1511 06/03/2010

Attachment 1, Volume 13, Rev. 1, Page 5 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 6 of 48 ITS 3.8.1 3/4,8 ELECTRICAL POWER SYSTEMS 3/4,8,1 A,e, SOURCES QPERATING LIMITING CONDITION FOR OPERATION LC03.8.1 3,8,1.1 As a minimuli. the following A,C, electrical power sources shall be OPERABLE:

a, Two qualified circuits between the offsite transmission network and the onsite Class IE A,C, electrical power distribution systell, and . _ _ - - - - - - - - - - - - - - - - - - - - J LA01 b.

SR 3.8.1.4 A separate fuel storage system containing a minimum volumer--_ _~ See of 32 000 allons of fuel, and ITS 3.8.3 J APPLICABILITY: HODES 1, 2, 3 and 4. '--------------------------1 LA01 ACIION:...._ _ --------;----{-1~A~dd~P~ro~p~os~e~d~AC~T~IO~N~S~N~o~te}I---------~8 a,

ACTION A ACTION F b,

ACTION B _

ACTION F Add proposed ACTION D Note ACTION D With one offsite circuit and one diesel generator the above ectrica owe 0 0 erable demonstrate the OPERABILITY of the remaining A.C, sources by performing RequiredActionA.1-------1Survel1lance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafte~ by performing Surveillance Required Action B . 3 . 2 - - - - - - = = - - - - - : - - - - - - - -

DAVIS-BESSE, UNIT 1 3/4 8-1 Amendment No. 5, 97, 293, 206 Page 1 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 6 of 48 Attachment 1, Volume 13, Rev. 1, Page 5 of 323

Attachment 1, Volume 13, Rev. 1, Page 6 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 7 of 48 ITS 3.8.1 ELECTRICAL POWER SYSTEMS RequiredActionB.3.2~ uirement 4.8.1.1.2.a.4 within ACTION D he inoperable sources to OPERABLE status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or be in ACTION F -----------~ within at east HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN the followin 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . With the inoperable offsite source RequiredActionBA ---.,restored, restore two diesel generators to OPERABLE status within da s from the time of the initial loss or be in at least HOT ACTION F - - - - - - STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the ollowing 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . With the inoperable diesel generator res ore, restore two offsite power sources to OPERABLE status Required Action A.3 ----------1 i thi n 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the time of the i nit i all oss or be in at ACTION F eas Wlt 1n t e next 6 ours and in COLD SHUTDOWN within the folloWing 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

ACTION C d. With two of the demonstrate the Surveillance Re once per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ACTION C ACTION F Required Action A.3 ----....,

ACTION F ACTIONE e. With two of the above required diesel generators inoperable,

~

emonstrate the OPERABILITY of two offsite A.C. circuits by Required Action B.1 performi ng Surve i 11 ance Requ i remen t 4.8. 1. 1. 1. a with in one hour d at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; ~store at least one of ACTIONE LEhe inoperable diesel generators to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

___________-----1l<)r be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD ACTION F l..s.HUTDOWN within the follow' Restore at least two RequiredActionBA---~diesel generators to OPERABLE status within 7 days from time of

__ _ _ _~~*~i~ttia~lcol~oDss~!clr be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ACTION F Lind in COLD SHUTDOWN with i n the fo 11 owi ng 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . ,-- -=-::.,..,...,-,

_ - - - - - - - - - - - - - - - - - - - - - - - - - - 1 Add proposed ACTION I SURVEILLANCE REQUIREMENTS 4.B.l.l.l Each of the above required qualified circuits between the offsite transmission network and the onsite Class IE A.C. electrical power distribution system shall be:

SR 3.8.1.1 a.

SR 3.8.1.9 b.

4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE: L10 SR 3.8.1.2,

~~ ;:~~;: ----a=-*'----j~~s SR 3.8.1.6, I ~~~ t b~~~e L!!!.!!..:...-~~:..s:.!L...J,!!:;J~L!!.!!<:"_!I..Ll.J.JL.llL...J.ill~L.J::..l/...LU..U.""---...l..LL..lJ>4p'_r' SR 3.8.1.7 DAVIS-BESSE, UNIT 1 3/4 8-2 Amendment No. 97,107,203,206,219 Page 2 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 7 of 48 Attachment 1, Volume 13, Rev. 1, Page 6 of 323

Attachment 1, Volume 13, Rev. 1, Page 7 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 8 of 48 ITS 3.8.1 r--------l Add proposed SR 3.8.1.2 Note 1 ELECTRICAL POWER SYSTEMS Add proposed SR 3.8.1.2 Note 2 SURVEILLANCE REQUIREMENTS (Continued)

SR 3.8.1.4 1. Verifying the fuel 1evel in the day fuel tank. See ITS 3.8.3 J

the fuel level in the fuel storage tank.

SR 3.8.1.7 3. Verifying the fuel transfer pump can Add proposed steady state fers fuel from the storage system to voltage and frequency Add proposed SR 3.8.1.2 4. SR 3.8.1.3 Notes 1 and 2 SR 3.8.1.2 Note - - - - - - - - - - i SR 3.8.1.3 Verifying t e diesel generator is al gned to provide~_~==============~~

standby po er to the associated esse tial busses.

SR 3.8.1.6 7. Verifying that the automatic load sequence timer is OPERABLE with each load sequence time within +/- 10% of its required~~_ _~~~~

va1 ue. Add proposed SR 3.8.1.5

b. At least once per 92 days by verifying that a sample of diesel fuel from the fuel storage tank is within the acceptable limits specified in !able 1 of ASTH D975-68 when checked for viscosity,

, - - - - - - - - l 31 r---==--------------------J A05

c. At SR 3.8.1.4 1. Verifying the fuel level in the day fuel tank. L10

2. Verifying the fuel level in the fuel storage tanko See ITS 3.8.3 J

SR 3.8.1.7 3. Verifying the fuel transfer pump can be started and transfers fuel from the storage system to the day tank.~~--~~~~~_,

r - - - - - - - - - - - - - - - - - - - - - - - - - - l Add proposed SR 3.8.1.8 Note SR 3.8.1.8 4. and ' - - - - - - - - - - - '

Add proposed voltage and frequency SR 3.8.1.3 5.

Verifying t e diesel generator is al *gned to provide standby pow r to the associated esse tial busses.

SR 3.8.1.6 1. Verifyingothat the automatic load sequence timer is OPERABLE with each load sequence time within +/- 10% of its required val ue.

DAVIS-BESSE, UNIT 1 3/4 8-3 Amendment No. ~5, 97, 195,203 Add proposed SR 3.8.1.3 Notes 1 and 2 Add proposed SR 3.8.1.3 Notes 3 and 4 Page 3 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 8 of 48 Attachment 1, Volume 13, Rev. 1, Page 7 of 323

Attachment 1, Volume 13, Rev. 1, Page 8 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 9 of 48 ITS 3.8.1 ELECTRICAL POWER SYSTEMS L08 SURVEILLANCE REQUIREMENTS (Continued)

Add proposed SR 3.8.1.10 Note 2 d.

SR 3.8.1.10 1. Verifying the generator capability to reject a load equal to the largest single M08 emergency load supplied by the generator without tri in.

Add proposed SR SR 3.8.1.15 2. Simulating a loss of offsite power in conjunction with a safety features actuation 3.8.1.15 Note 1 system (SFAS) test signal, and:

actual or (a) Verifying de-energization of the essential busses and load shedding from the essential busses.

(b) Verifying the diesel starts from ambient condition on the auto-start signal, energizes the essential busses with permanently connected loads, energizes thc auto-connected essential loads through the load sequencer and operates for Add proposed start

.::: 5 mjnutes while its generator i loaded with the essential loads. - - - - - - - I time limit and steady state voltage and frequency limits SR 3.8.1.12 (c) Verifying that all diesel generator trips, except engine overspeed and generator differential, are automatically bypassed upon loss of voltage on the essential bu and/or an SFAS test signal.

SR 3.8.1.13 3. /Verifying the diesel generator operates for> 60 minutes willIe loaded to > 2000 k\ M06 Add proposed Note 1 and Note 3

4. Deleted.

e. At least once per 30 m nths by subjecting the diesels to an insp ction in accordance with procedures prepared i conjunction with its manufacturer's rec mmendations for this I - - - - - - - - - - - { LA03 class of standby servi e.'

Add proposed SR 3.8.1.5, SR 3.8.1.11, and SR 3.8.1.14 M04 1 - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 LA03 not applicable.

DAVIS-BESSE, lJNlT I 3/48-4 Amendment No. 97,105,141,219,273 Page 4 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 9 of 48 Attachment 1, Volume 13, Rev. 1, Page 8 of 323

Attachment 1, Volume 13, Rev. 1, Page 9 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 10 of 48 ITS 3.8.1 3/4 LIMITING CONDITIONS FOR OPERATIQH AND SURYEILLANCE REQUIREMENTS 3/4.0 APPLlcABlun LIMnING CONOInON fO~ OPERAnON 3.0.1 limiting ConditIons for Operation and ACTION requirements shall be applicable during the OPERATIONAL HOOES or other conditions specified for each specification.

3.0.2 Adherence to the requirements of the Limiting Conditton for Operation and/or associated ACTION within the specified time Interval shall constitute compliance wfth the speciflcatfon. In the event the LimitIng Condftlon for Operatfon fs restored prior to expiration of the specffted time Interval, completion of the ACTION statement is not required. .

3.0.3 When a LIMIting Condition for Operat10n Is not met, except as proVided in the associated ACTION requirements, action shall be Initiated within I hour to place the unIt 1n a HODE in which the SpecIfIcation does not apply by placIng 1t, as applIcable, 1n:

1. At Ieast HOT STANDBY wah 1n the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , H See ITS 3.0 J

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

3. At least COLD SHUn1)OWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Where corrective neasures afe completed that pe~it operat10n under the ACTION reQufrements, the ACTION m~ be taken in accordance wIth the specified tfMe limits as JDeasured frolll the t1me of failure to meet'the l1M1tlng Condition for Operation. Exceptions to these requirements are stated In the individual SpecifIcatIons.

3.0.4 Entry 1nto an OPERATIONAL HODE or other speclf1ed applicability.

condition sha11-not'be made unless the condit10ns of the limiting Condit10n for Ope rat i on are IIlet wi thout re11 ance on provi sions coota i ned' in the ACTION statements unless otherwise excepted. This,provision shall not prevent passage through OPERATIONAL HODES as required to comply with ACTION statements. . .

Required Actions A.2, B.2, and C.1 L04 3.0.6 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service'under administrative control solely t¥Y f perform testIng required to demonstrate its OPERABILITY or the OPERABILI 0 other equIpment. This is an exception to Specification 3.0.2 for the system See ITS 3.0 J

returned to service under administrative control to perform the testIng requIred to de~onstrate OPERABILITY.

OAVIS-BE~SE, UNIT 1 3/4 '0-1 Amenqment Ho. 11,135,163,224 Declare required features inoperable.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for proposed Required Action A.2 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for proposed Required Action B.2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Required Action C.1 Page 5 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 10 of 48 Attachment 1, Volume 13, Rev. 1, Page 9 of 323

Attachment 1, Volume 13, Rev. 1, Page 10 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 11 of 48 ITS 3.8.1 fNSTRUMENTATIO 3/4.3.2 SAFETY SYSTEM INSTRUMENTATIO SAFETY FEATURfS ACTUATIO SYSTEM INSTRUME ATlON LIMITfNG CONDITION FOR OPERATION Leo 3.8.1 3.3.2.1 The Safety Features Actuation System (SFAS) functional units shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the Allowable Value column of Table 3.3-4.

APPLICABILITY: As shown in Table 3.3-3.

ACTION: I

a. With a SFAS functional unit trip setpoint less conservative than the value shown in the ---

ITSSee 3.3.5]

Allowable Values column of Table 3.3-4, declare the functional unit inoperable and apply the and applicable ACTION req,uirement of Table 3.3-3, until the functional unit is restored to ITS 3.3.8

'-

OPERABLE status with the trip setpoint adjusted consistent with Table 3.3-4.

b. With a SFAS functional unit inoperable, take the action shown in Table 3.3-3.

SURVEILLANCE REQUIREMENTS

/

ITSSee J 3.3.5, ITS 3.3.6, ITS 3.3.7, and 4.3.2.1.1 Each SFAS functional unit shall be demonstrated OPERABLE by the performance of the ITS 3.3.8 CHANNEL CHECK. CHANNEL CAUBRATION and CHANNEL FUNCTIONAL TEST during the MODES and at the frequencies shown in Table 4.3-2.

4.3.2.1.2 The logic for the RCS pressure operating bypasses shall be demonstrated OPERABLE during the at power CHANNEL FUNCTIONAL TEST of functional units affected by the RCS pressure operating bypass operation. This RCS pressure operaling bypass function shall be demonstrated See ITS 3.3.5 J

OPERABLE at least once per REFUELfNG lNTERV AL during CHANNEL CALIBRATION testing of each functional unit affected by the RCS pressure operating bypass operation.

4.3.2.1.3 The SAFETY FEATURES RESPONSE TIME of each SFAS function shall be demonstrated to be within the limit at least once per REFUELING INTER VAL, Each test shall include at least one functional unit per function such that all functional units are tested at least once every N times the REFUELfNG INTERVAL where N is the total number of redundant functional units in a specific SFAS ITSSee 3.3.5 and J

ITS 3.3.8 function as shown in the "Total No. of Units" Column of Table 3.3-3.

The response times (except for manual initiation) include diesel generator starting and sequence loading delays, when applicable. The response time limit (except for manual initiation) includes movement of See ITS 3.3.5 J

valves and attainment of pump or blower discharge pressure.

DAVIS-BESSE. UNIT I 3/4 3-9 Amendment No. Z I B. 225. 241, 243, :159,275 Page 6 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 11 of 48 Attachment 1, Volume 13, Rev. 1, Page 10 of 323

ITS 3.8.1 ITS 8

o TABLE 3.3-3 (Continued)

>>

r -+

r-+

SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION ( >>

r -+

r-+

Q) al

~ / 7 LA04 Q)

C) MINIMUM C)

r j UNITS APPLICABLE ::r 3 FUNCTIONAL UNIT OPERABLE MODES ACTION 3 CD ~ CD

J 3. MANUAL ACTUATION :::J r-+ r-+

~ ~

a. SFAS (except Containment

< Spray and Emergency Sump See J <

o Recirculation) 2 2 2 1,2,3,4 12 ITS 3.3.6 o c c 3 ...:iii: b. Containment ~pray 2 2 2 1,2,3,4 12 3 CD CD

~ ~ ~

LCO 3.8.1.c 4. SEQUENCE LOGIC CHANNELS w W

u a. Sequencer ::u CD CD

< b. Essential Bus Feeder <

Z

~

i

? Breaker Trip Degraded Voltage Relay (DVR) 4***** 2fBUS 2/BUS 1,2,3,4 15#

~

"U "U Q) Q)

<C c. Diesel Generator Start, <C CD Load Shed on Essential Bus CD

~ Loss of Voltage Relay (LVR) 4 2/BUS 2/BUS 1,2,3,4 15# ~

~ ~

o 5. INTERLOCK CHANNELS o See J w . ITS 3.4.14 W I\.) a. Decay Heat Isolallon Valve I 1 1 1,2,3 13# I\.)

-

w N b. Pressurizer Heaters 2 2 2 3" 14

- W

'.J U1 I u.. H: IT;~e3.5 J Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 12 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 12 of 48 Page 7 of 10

Attachment 1, Volume 13, Rev. 1, Page 12 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 13 of 48 ITS 3.8.1 TABLE 3.3-3 (Continued)

TABLE NOTATION

Trip function may be bypassed in this MODE with RCS pressure below 1800 psig. Bypass shall be automatically removed when RCS pressure exceeds 1800 psig. See ITS 3.3.5 J

.. Trip function may be bypassed in this MODE with RCS pressure below 660 psig. Bypass shall be automatically removed when RCS pressure exceeds 660 psig.

... DELETED

.... DELETED

- - - - All functional units may be bypassed for up to one minute when starting each Reactor Coolant See ITS 3.3.8 J

Pump or Circulating Water Pump.

.... **-. When either Decay Heat Isolation Valve is open.

See ITS 3.3.5 J

~#~T~h~elP~ro~v~i~si~o~s~o~f~S~p~.e~c~ifi~lc~a~ti~on~3~.O~.4!1r~e~n~0~t~ap~p~l~ic~a~bl~e=.} - - - - - - - - - - - - - - - - - - - - - ( A09 ACTION STATEMENTS ACTION 10 - With the number of OPERABLE functional units one less than the Total Number of See ITS 3.3.5 J

Units, STARTUP and/or POWER OPERATION may proceed provided, within one hour (except as noted below), the inoperable functional unit is placed in the tripped condition. When one functional unit is placed in an inoperable status solely for performance of a CHANNEL FUNCTIONAL TEST, a declaration of inoperability and associated entry into this ACTION statement may be delayed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , provided at least two other corresponding functional units are OPERABLE.

ACTION II - With any component in the Output Logic inoperable, trip' the associated'components within one hour or be in at least HOT STANDBY within Ihe next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD See ITS 3.3.7 J

SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

DAVIS-BESSE, UNIT I 3/43-12 Amendment No. 28,37,52,102,135, 159,186,211,218,221,259 Corrected by letter dated 6/2/98 Page 8 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 13 of 48 Attachment 1, Volume 13, Rev. 1, Page 12 of 323

Attachment 1, Volume 13, Rev. 1, Page 13 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 14 of 48 ITS 3.8.1 TABLE 3.3-3 (Continued)

ACTION STATEMENTS ACTION 12 - With the number of OPERABLE Units one less than the Total Number of Units, restore the inoperable functional unit to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the See ITS 3.3.6 J

next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

ACTION 13 - a. With less than the Minimum Units OPERABLE and indicated reactor coolant pressure ~ 328 psig, both Decay Heat Isolation Valves (DHll and DHI2) shall be verified closed.

b. With Less than the Minimum Units OPERABLE and indicated reactor coolant pressure < 328 psig operation may continue; I

I See ITS 3.3.14 J

however, the functional unit shall be OPERABLE prior to increasing indicated reactor coolant pressure above 328 I psig.

ACTION 14 - With less than the Minimum Units OPERABLE and indicated reactor coolant pressure < 328 psig, operation may continue; however, the.

functional unit shall be OPERABLE prior to increasing indicated ~4--~ See ITS 3.3.5 J

reactor coolant pressure above 328 psig, or the inoperable functional unit shall be placed in the tripped state.

ACTION G ACTION 15 - a. With the number of OPERABLE units one less than the Minimum Units Operable per Bus, place the inoperable unit in the tripped condition within one hour. For functional unit 4.a the sequencer shall be placed in the tripped condition b physical removal of the sequencer module. T e inoperable unc lona un, may e ypasse or up 0 hours0 days 0 hours 0 weeks 0 months for ~---~ See ITS 3.3.8 J

surveillance testing per Specification 4.3.2.1.1:

ACTION H b. With the number of OPERABLE units two less than the Minimum Units Operable per Bus, declare inoperable the Emergency r-----L-------~

Diesel Generator associated with the functional units not meeting the required minimum units OPERABLE and take the ACTION required of Specification 3.8.1.1.

DAVIS-BESSE, UNIT 1 3/4 3-12a Amendment No. 28,52,192,135,211,218 Page 9 of 10 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 14 of 48 Attachment 1, Volume 13, Rev. 1, Page 13 of 323

ITS 3.8.1 8

TABLE 4.3-2 (Continued)

>>

r -+

r-+ t:l SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEIl-LANe REQUIREMENTS

>>

r -+

r-+

Q) L06 Q)

C) CHA~NEL MODES IN WHICH C)

III

r

~ CHANNEL CHANNEL FUNC IONAL SURVEILLANCE ::r 3 ~ FUNCTIONAL UNIT CHECK CALffiRATION I REOUrRED x 3

!'l I T r ST CD CD

J :::J r-+ 4 . SEQUENCE LOGIC CHANNELS r-+

~

~ a. Sequencer NA M - SR 3.8.1.6 1.2,3.4 ~

~ M(3)

b. Essential Bus Feeder Breaker Trip, S A(3) 1,2,3,4

< Degraded Voltage Relay (DVR) I <

0 o

c. Diesel Generator Start, Load Shed on S A(3) M(3) 1,2,3,4 I 38J c c Essential Bus, Loss of Voltage Relay 3 (LVR) 3 CD ... CD

~ ~ ~

w 't' W

~

5. INTERLOCK CHANNELS See J ITS 3.4.14

u CD I W: ay ~ea! Isolarioo Valye S R H 1 2 3 4 J ::u CD See

b. essunzer Heater S R ** 3 #11

< ITS 3.3.5 I <

~ ~

T ABLE NOT AnON "U Manual actuation switches shall be tested at least once per REFUELING INTERVAL. All other circuitry associated with manual "U

Q) I (I) See Q)

<C CD I

~ safeguards actuation shall receive a CHANNEL FUNCTIONAL TEST at least once per 31 days. ITS 3.3.6 J <C CD

~ ~

1 1(2) The CHANNEL FUNCTIONAL TEST shall include exercising the transmitter by applying either vacuum or pressure to the appropriate See J

~ ITS 3.3.5 ~

side of the transmiller.

0 o

t 1(3) The as-left instrument selling shall be returned to a setting within the tolerance band of the trip setpoint established to protect the safety W See J w I\.) limit. ITS 3.3.8 I\.)

-

w

- w

... See Specification 4.5.2.d.1 I I I See J ITS 3.4.14

1. When either Decay Heal Isolation Valve is open. See J ITS 3.3.5

'-J

'"

U"I Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 15 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 15 of 48 Page 10 of 10

Attachment 1, Volume 13, Rev. 1, Page 49 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 16 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 --------------- --------------- NOTE-----------------------------

All DG sta s may be preceded by an engine prelub period.

----------------------------------------------------- -

Verify, w en started simultaneously from standby 10 years condition each DG achieves, in ~ [10] seconds, voltage" [3740] V and ~ [4580] V, and frequency

~ [58.8] ~z and ~ [61.2] Hz.

BVVOG STS 3.8.1-16 Rev. 3.1,12/01/05 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 16 of 48 Attachment 1, Volume 13, Rev. 1, Page 49 of 323

Attachment 1, Volume 13, Rev. 1, Page 53 of 323 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 17 of 48 JUSTIFICATION FOR DEVIATIONS ITS 3.8.1, AC SOURCES - OPERATING

19. ISTS SR 3.8.1.20 is not included in the Davis-Besse ITS. This SR is intended to periodically verify acceptable electrical and physical independence of the EDGs and associated electrical distribution systems. Adequate independence (both electrical and physical) of the EDGs and associated electrical distribution systems was a requirement (and has been established in) the original plant design. Furthermore, existing maintenance practices and configuration control practices are judged to be sufficient to ensure continued acceptable separation and independence. Thus, there is no need to periodically perform this SR to demonstrate continued acceptable independence or simultaneous start capability. This is also consistent with the current licensing basis.

20. ISTS SR 3.8.1.8 (ITS SR 3.8.1.9) has been revised to include two parts consisting of: a) an automatic and manual transfer from the unit auxiliary source (i.e., main generator) to the pre-selected offsite circuit; and b) an automatic and manual transfer from the normal offsite circuit to the alternate offsite circuit. These changes were made consistent with the manner in which the CTS Surveillance is performed.

However, a Note has also been added to ISTS SR 3.8.1.8 (ITS SR 3.8.1.9) that states SR 3.8.1.9.a is only required to be met when the unit auxiliary source is supplying the electrical power distribution subsystem. This change is necessary since the automatic and manual transfer from the unit auxiliary source to the pre-selected offsite circuit is not necessary when the offsite circuit is supplying onsite power. In this situation, the offsite circuit is performing its function by supplying the on site power. Also, due to the Note addition, the remaining Note has been renumbered. Furthermore, since the unit auxiliary source is manually placed in service when in MODE 1, the Note restriction has only been applied to the automatic transfer portion of SR 3.8.1.9.a and all portions of the transfer from the normal offsite circuit to the alternate offsite circuit.

Davis Besse Page 4 of 4 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 17 of 48 Attachment 1, Volume 13, Rev. 1, Page 53 of 323

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 18 of 48 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 power sources shall be OPERABLE:

a. Two qualified circuits* between the offsite transmission network and the onsite Class 1E AC Electrical Power Distributio'n System;

b. Two emergency diesel generators (EDGs) each capable of supplying one train of the onsite Class 1~ AC Electrical Power Distribution System; and

c. Two load sequencers for Train 1 and two load sequencers for Train 2.

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

ACTIONS

- - - - - - - - .- - - - - - - - - - - - N O T E - - - - - - - - - - - - - - - '- - - - - - -

LCO 3.0.4.b is not applicable to EDGs.

, CONDITION REQUIRED ACTION COMPLETION TIME A, One offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE offsite circuit.

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A,2 De,clare required feature(s) .24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from with no offsite power discovery of no offsite available inoperable when power to one train its redundant reqUired concurrent with feature(s) is inoperable. inoperability of redundant required feature(s)

AND Davis-Besse 3.8.1-1 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 18 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 19 of 48 AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Restore offsite circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. One EDG inoperable. 6.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE offsite circuit(s). AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.2 Declare required feature(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from supported by the inoperable discovery of EDG inoperable when Its ConditionB redundant reqUired concurrent with feature(s) is inoperable. inoperability of redundant required feature(s)

AND B.3.1 Determine OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months EDG is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE EDG.

AND B.4 Restore EDG to 7 days OPE;RABLE status.

Davis-Besse 3.8.1-2 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 19 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 20 of 48

- AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two offsite circuits C,1 Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from

.inoperable. inoperable when its discovery of redundant required ConditionC feature(s) is inoperable. concurrent with inoperability of redundant required

,

'feature(s)

AND C.2 Restore one offsite. circuit to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

\

OPERABLE status.

\

D. One offsite circuit ------NOTE--------'-

inoperable. Enter applicable Conditions and Required Actions oftC03.8.9. ,

AND* "Distribution Systems - Operating,"

when' Condition 0 is entered with no One EDG inoperable. ACpower source to any train.

~-------

0.1 Restore offsite circuit to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

\

OPERABLE status.

OR

'. 0.2 Restore EDG to OPERABLE status. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two EDGs inoperable.. E.1 Restore one EDG to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

Davis-Besse . Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 20 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 21 of 48 AC Sources :- Operating 3.8.1 ACTIONS (continued)

CONDITiON REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Associated Completion Time of Condition A, 8, AND C, D, or E not met.

F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. ------NOTE----------- G.1 Remove inoperable load 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Separate Condition entry sequencer.

is allowed for each train.

I One or more trains with one load sequencer inoperable.

H. ----NOTE--------- H.1 . Declare associated EDG Immediately Separate Condition entry inoperable.

s allowed for each train.

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

OR One or more trains with two load sequencers inoperable.

I. Three or more AC 1.1 Enter LCO 3.0.3. Immediately sources inoperable.

Davis-Besse 3.8.1-4 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 21 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 22 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each offsite circuit.

SR 3.8.1.2 -----------NOTES-------------

1. All EDG starts may be preceded by an engine prelube period and followed by a warmup.

period prior to loading.

2. A modified EDG start involving idling and/or 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 EDG starts from standby conditions and 31 days achieves steady. state voltage ~ 3744 V and

5 4400 V, and frequency ~ 59.5 Hz and s 60.5 Hz.

SR 3.8.1.3 ------------NOTES-----,------------

1. EDG 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 EDG 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 3.8.1.8.

Verify each EDG is synchronized and loaded and 31 days operates for 2:60 minutes at a load;:>; 2340 kWand s 2600 kW.

SR 3.8.1.4 Verify each day tank contains <?: 4000 gal of fuel oil. 31 days Davis-Besse 3.8.1-5 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 22 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 23 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.5 Check for and remove accumulated water from each 31 days day tank.

SR 3.8.1.6 Verify interval between each sequenced load block 31 days is within +/- 10% of design interval for each emergency (oad sequencer and each emergency time delay relay.

SR 3.8.1.7 Verify the fuel oil transfer system operates to 92 days transfer fuel oil from fuel oil storage tank to the day tank. .

SR 3.8.1.8 -------------NOTE------------------

All EDG starts may be preceded by an engine prelube period.

_._--_._--------

Verify each EDG starts from standby condition and 184 days achieves:

a. In:5 10 seconds, voltage ~ 4031 V and frequency ~ 58.8 Hz; and

b. Steady state voltage:2': 3744 V and :5 4400 V, and frequency :2': 59.5 Hz and :5 60.5 Hz.

Davis-Besse 3.8.1-6 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 23 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 24 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.9 --------NOTES---------

1. SR 3.8.1.9.a is only required to be met when the unit auxiliary source is supplying the electrical power distribution subsystem.

2. The automatic transfer portion of SR 3.8.1.9.a and all of SR 3.8.1.9.b shall not normally be performed in MODE 1 or 2. However, they may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify automatic and manual transfer of AC power 24 months sources from:

a. The unit auxiliary source to the pre-selected offsite circuit; and .

b. The normal offsite circuit to the alternate offsite circuit.

Davis-Besse 3.8.1-7 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 24 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 25 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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 plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

2., If performed with the EDG synchronized with offsite power, it shall be performed within the power factor limit. 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 EDG rejects a load greater than or equal, 24 months to its associated single largest post-accident load, and following load rejection, the frequency ;s 566.75 Hz.'

Davis-Besse 3.8.1-8 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 25 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 26 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 - - - - - - - - - - 'NOTES------------

1. All EDG 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 plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

---,--------------------------

Verify on an actual or simulated loss ofoffsite power 24 months signal:

a. De-energization of essential buses;

b. Load shedding from essential buses; and

c. EDG auto-starts from standby condition and:

1. Energizes permanently connected loads in ~ 10 seconds;

2. Energizes auto-connected shutdown loads through individual time delay relays;

3. . Maintains steady-state voltage ~ 3744 V and ~4400 V;

4. Maintains steady-state frequency

~ 59.5 Hz and ~ 60.5 Hz; and

5. ' Supplies permanently connected and auto-connected shutdown loads for

~ 5 minutes.

Davis-Besse 3.8.1-9 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 26 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 27 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 -----------NOTE--------------

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. Credit may be taken for unplanned events that satisfy this SR.

Verify each EDG's noncritical automatic trips are 24 months bypassed on actual or simulated loss of voltage signal on the essential bus or an actual or simulated Safety Features Actuation System (SFAS) actuation signal.

SR 3.8.1.13 --------------NOTES---------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. 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. Credit may be taken for unplanned events that satisfy this SR.

3. If performed with EDG synchronized with offsite power, it shall be performed within the power factor limit. 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 EDG operates for ~ 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months s: 24 months

a. For ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 2730 kW and

2860 kW; and

b. For the remaining hours of the test loaded

~ 2340 kW and::; 2600 kW..

Davis-Besse 3.8.1-10 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 27 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 28 of 48 AC Sources* Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.14 -----------NOTES-----------

1. This Surveillance shall be performed within 5 minutes of shutting down the EDG after the EDG has operated ~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months loaded 2: 2340 kW and::; 2600 kW.

Momentary transients outside of load range do not invalidate this test.

2.. All EDG starts may be preceded by an engine prelube period.

Verify each EDG starts and aChieves: 24 months

a. In::; 10 seconds, voltage 2: 4031 V and frequency 2: 58.8 Hz; and

b. Steady state voltage;;:: 3744 V and::; 4400 V, and frequency;;:: 59.5 Hz and::; 60.5 Hz.

Davis-Besse 3.8.1-11 Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 28 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 29 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.15 NOTES-------------

1. All EDG starts may be preceded by an engine prelube period.

2. This Surveillance shall not nonnally be perfonned in MODE 1, 2, 3, or 4. However, portions of the Surveillance ,may be perfonned to reestablish OPERABILITY provided an assessment detennines the safety of the plant 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 SFAS actuation signal:

a. De-energization of essential buses;

b. Load shedding from essential buses;

c. EDG auto-starts from standby condition and:

1. Energizes permanently connected loads in ~ 10 seconds;

2. Energizes auto-connected emergency loads through load sequencer and individual time delay relays;

3. Achieves steady-state voltage c 3744 V and:$; 4400 V;

4. Achieves steady-state frequency c 59.5 Hz and ~ 60.5 Hz; and ,

5. Supplies permanently connected and auto-connected emergency loads for c 5 minutes.

Davis-Besse Amendment 279 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 29 of 48

ITS 3.8.1 G

ITS 3.0 LIMITING CONDITIONS FOR OPERATION 4.0 SURVEILLANCE REQUIREMENTS 381 3.9 AUXILIARY ELECTRICAL SYSTEMS 4.9 AUXILIARY ELECTRICAL SYSTEMS

>>

>>

Q) Applicability: Q)

(") (")

T ::::T Applies to the auxilia ectrical power system. Applies to the periodic testing requirements e auxiliary 3

(I) electrical system. 3 (I)

~ Objective: ~

Objective:

~ ~

.- an adequate supply of electrical er during

<

T~ure lant operation. Verify the operabili he auxiliary electrical system.

-<

0 o s:::: Specification: Specification: s::::

3 Applicability 3 (I) A. Surveillance testing shall be performed as follows: (I)

LCO 3.8.1

~ ~

W W

0 LCO 3.8.1.a 1.

;:0 (I) (I)

< <

~ ~

. LA. 1

"'tJ "'tJ Q) Q) to to (I) (I)

U1 U1 0 o t \,) t \,)

CD CD Add proposed SR 38.1.1 and SR 38.1.6

-

U1 ~ ~

- U1 qualified circuits between 199 10/16/87 3.9/4.9 the offsite transmission network and the onsite Amendment No. 51 Class 1E AC Electrical Power Distribution System Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 30 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 30 of 48 Page 1 of 5

ITS 3.8.1 G

ITS 3.0 LIMITING CONDITIONS FOR OPERATION 4.0 SURVEILLANCE REQUIREMENTS

>> LCO 381.b 2. >>

LA3

Q) Q)

(") (")

T 3. (a) 4160V Buses #15 and #16 are energized. ::::T 3

(I)

See ITS 3.8.7 } 3 (I)

(b) 480V Load Centers #103 and #104 are

~ ~

eneraized.

~ ~

.- 4. All station 24/48, 125, and 250 vol~ batteries are ~ See ITS 3.8.4, ITS 3.8.6, }

.-

<

0 charged and in service, and associated battery I I and ITS 3.8.7 l A2 I <

0 s:::: s::::

3 (I) 3 (I)

~ ~

W ACTION F, ~

ACTION G

0

;:0 (I) (I) 1.

< :<

~ From d after the date at incoming power is ~

. avai ble from only 0 line, reactor operatio IS

.

"'tJ p missible only du . g the succeeding sev. n days "'tJ Q) Q) to nless an additio I line is sooner place In service to (I) providing both e emergency diesel a nerators are (I) en operable. en 0 0 t \,) t \,)

CD CD

-

U1

- U1 I 3.9/4.9 200 08/27/02 Amendment No. a+,:l-(l4., 129 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 31 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 31 of 48 Page 2 of 5

ITS 3.8.1 ITS G

ITS 3.0 LIMITING CONDITIONS FOR OPERATION 4.0 SURVEILLANCE REQUIREMENTS

>>

= 2. Reserve Transformers Add proposed Note 1 to SR 3.8.1.2 >>

D) :=

D)

(') Add proposed Note 2 to SR 3.8.1.2 (')

T ACTION A

T 3 3 CD Add proposed steady state CD

J B. 3. vo~age and frequency limits ::J

~

- .-

3. Standby Diesel Generators <

~ 0 s: ACTION B SR 3.8.1.3

a. 1) From and after the date that one of the s:

3 Add proposed Note 1 CD diesel generators is made or found to be to SR 3.8.1.12 3 inoperable, reactor operation is permissible CD

~

SR3.8.1.12 ~

W Add proposed Required Action B.1 only during the succeeding 7 days provided W

that the operable diesel generator is

C demonstrated to be operable within ;;C CD I--..,-r.,....,..,.---.,,------

: -:----,

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

< ~

~ (a) ~

.

"'tJ "'tJ D)

D) lC (b) Add proposed steady state lC CD voltage and frequency limits M.6 I CD

...... ......

o 0 N N CD SR 3.8.1.13 CD

-

C1I ACTION E

- C1I Add proposed Required Action E.1 ACTION F L.4 M.3 3.9/4.9 201 08/27/02 Amendment No. 25, 51, 77, 129 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 32 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 32 of 48 Page 3 of 5

ITS 3.8.1 G

ITS 3.0 LIMITING CONDITIONS FOR OPERATION 4.0 SURVEILLANCE REQUIREMENTS

>> L.g

b. For the diesel generators to be considered b. 1) Once a month the quantity of diesel fuel } >>

=

D) operable, there shall be a minimum of available shall be logged. See ITS 383 :=

D)

(') 38,300 gallons of diesel fuel (7 days supply (')

T for 1 diesel generator at full load @ 2500 :::T SR 3.8.1.5 3 KW) in the diesel oil storage tank. Verify the fuel oil 3 CD transfer system CD

J operates to transfer ::J See ITS 3.8.3 fuel oil from storage

~

- and ITS 5.5 Once a month a sample of diesel fuel shall tank to the day tank. ~

{ be taken and checked for quality.

~ c. When a diesel generator is required to be operable, maintain air pressure for both

./

i I I I

Add requirements of fuel oil transfer system f-G - <

o s: c. Verify each required operable diesel to transfer fuel oil from M.8 associated air starting receivers day tank to associated s:

3 generator air start receiver pressure is 2: 165 psig. base tank 3 CD 2: 165 psig once per month. Il CD

~

1) With one diesel generator starting air ~

W See ITS 38.3 W receiver pressure < 165 psig, restore both ~ }--1

C starting air receivers pressure to ;;C CD 2

165 psig within 7 days, or declare the CD

< Add proposed SR 3.8.1.4, SR 3.8.1.7, SR 3.8.1.8, associated diesel generator inoperable. M.2 <

~

SR 3.8.1.9, SR 3.8.1.10, and SR 3.8.1.11

~

2) With both diesel generator starting air

"'tJ receivers pressure < 165 psig but "'tJ D)

D) lC 2: 125 psig, restore one starting air receiver lC CD to 2: 165 psig and enter TS LCD CD

0) 3.9.B.3.c.l, or restore both starting air 0) o receivers pressure to 2: 165 psig within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . If neither action can be o

N accomplished within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , declare the N CD CD

-

C1I associated diesel generator inoperable.

- C1I

3) With both diesel generator starting air receivers pressure < 125 psig, immediately declare the associated diesel generator inoperable.

3.9/4.9 202 08/27/02 Amendment No. ~, 75, SQ, 129 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 33 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 33 of 48 Page 4 of 5

ITS 3.8.1 G

ITS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for proposed Required Action A.2 }--G 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for proposed Required Action B.2 L.5 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for proposed Required Action C.1

'" I When a system, subsystem, train, component or device is determined to be inoperable soley because its emergency power

>> Required Actions >>

source is inoperable, or soley because its normal power source is inoperable, it may be considered operable for the purpose of: :;

A.1, B.2, and C.1 Q) satisfying the requirements of its applicable Limiting Condition for Operation provided: (1) its corresponding normal or Q)

(") emergency power source is operable; and (2) all of its redundant system(s), subsystem(s), trains(s), component(s) and device(s) (")

T are Operable, or likewise satisfy the requirements of this paragraph. ......1 - - - - - - - - - - - - - - - - - - - - - - ::::T 3

(I) 3 (I)

~

M. Operating - Operating means that a system or component is performing its specified functions. ~

i

~ N. Operating Cycle - Interval between the end of one refueling outage and the end of the next subsequent refueling outage. ~

.- I [ See ITS Chapter 1.0 } -

o. power Operation - Power Operation is any operation with the mode switch in the "Start-Up" or "Run" position with the reactor

<

0 critical and above 1% rated thermal power. <

o s:::: I p. Primary Containment Integrity - Primary Containment Integrity means that the drywell and pressure suppression chamber are s::::

3 intact and all of the following conditions are satisfied. 3 (I) (I)

~

1. All manual containment isolation valves on lines connecting to the reactor coolant system or containment which are not ~

W required to be open during accident conditions are closed. r See ITS Chapter 1.0, } W

2. At least one door in the airlock is closed and sealed. I ( ITS 3.6.1.1, ITS 3.6.1.2, and

0 ITS 3.6.1.3

;:0 (I) 3. All automatic containment isolation valves are operable or are deactivated in the closed position or at least one valve in (I)

< each line having an inoperable valve is closed <

~ 4. All blind flanges and man....ays are closed. ~

. protective Instrumentation Logic Definitions

"'tJ roo "'tJ Q) 1. Instrument Channel - An instrument channel means an arrangement of a sensor and auxiliary equipment required to Q) to generate and transmit to a trip system, a single trip signal related to the plant parameter monitored by that instrument to (I) (I) channel.

CD CD

2. Trip System - A trip system means an arrangement of instrument channel trip signals and auxiliary equipment required to 0 initiate a protection action. A trip system may require one or more instrument channel trip signals related to one or more o

See ITS Chapter 1.0 }

t \,) plant parameters to initiate trip system action. Initiation of the protective function may require tripping of a single trip system t \,)

CD (e.g., HPCI system isolation, off-gas system isolation, reactor building isolation and standby gas treatment initiation, and rod CD

-

U1 block), or the coincident tripping of two trip systems (e.g., initiation of scram, reactor isolation, and primary containment isolation) .

- U1

3. Protective Action - An action initiated by the protection system when a limit is exceeded. A protective action can be at channel or system level.

3 1/23/84 Amendment No. 21 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 34 of 48 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 34 of 48 Page 5 of 5

Attachment 1, Volume 13, Rev. 1, Page 40 of 295 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 35 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 ---- --------------------------NOT ------------------------------

DG starts may be prece ed by an engine prelube eriod.

Verify, when starte simultaneously from standby 10 years condition, [each] A and 2C] DG achieves:

a. In::;; [12] conds, voltage ~ [3740] Vand freque y ~ [58.8] Hz and

b. Ste dy state voltage ~ [3740] V and::;; ~580] V a tJ frequency ~ [58.8] Hz and::;; [61 ] Hz.

BWR/4 STS 3.8.1-16 Rev. 3.0, 03/31/04 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 35 of 48 Attachment 1, Volume 13, Rev. 1, Page 40 of 295

Attachment 1, Volume 13, Rev. 1, Page 43 of 295 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 36 of 48 JUSTIFICATION FOR DEVIATIONS ITS 3.8.1, AC SOURCES - OPERATING load interval will ensure that the time between the second and third load blocks is sufficient to ensure that the EDG can restore frequency and voltage prior to energizing the third load block. The "each" requirement also ensures that all subsequent load intervals (e.g., the third, fourth, etc.) do not impact the capability of the EDG to perform its intended function.

The second purpose described in the Bases for the SR is not related to the EDG; it relates to the ability of the individual loads to perform their assumed functions. Thus, if a time delay was too long, while the individual load may be inoperable, the EDG is not inoperable; the EDG can still perform its intended function. Thus, the upper limit should not be considered as an operability requirement for the EDG. If an individual load timer is too long, only the associated load should be considered inoperable. In addition, many of the load timers (the ones that affect the ECCS pumps) are required by ISTS 3.3.5.1, ECCS Instrumentation; thus the upper limits for these timers will be maintained in the ITS.

Furthermore, the actual values of the load interval limits (i.e., 10% of the design interval) are not included, consistent with current licensing basis. The actual values will continue to be under Monticello control in the appropriate plant procedures.

In addition, since this SR was added in response to an NRC question during the review of Revision 0 of the ITS submittal, the SR has been added at the end of the ITS 3.8.1 SRs (i.e., SR 3.8.1.13).

13. ISTS SR 3.8.1.20 is not included in the Monticello ITS. This SR is intended to periodically verify acceptable electrical and physical independence of the EDGs and associated electrical distribution systems. Adequate independence (both electrical and physical) of the EDGs and associated electrical distribution systems was a requirement (and has been established in) the original plant design. Furthermore, existing maintenance practices and configuration control practices are judged to be sufficient to ensure continued acceptable separation and independence. Thus, there is no need to periodically perform this SR to demonstrate continued acceptable independence or simultaneous start capability.

14. ISTS SR 3.8.1.8 requires verification of automatic and manual transfer of unit power supply from the normal offsite circuit to the alternate offsite circuit at a Frequency of 18 months. The Frequency of 18 months is bracketed. ITS SR 3.8.1.6 requires a similar Surveillance, however the Frequency has been changed to 24 months on a STAGGERED TEST BASIS for each division. This Surveillance is not currently required by the CTS, however testing is performed periodically to test these features and all features perform as required. Furthermore, the current Frequency for these tests are no more frequent than every second outage. Thus, the Frequency of 24 months on a STAGGERED BASIS for each division maintains this current Frequency. The proposed Frequency of 24 months on a STAGGERED TEST BASIS for each division is considered to be appropriate based on the reliability of the equipment.

15. ISTS SR 3.8.1.4 requires verification that the fuel oil level in the day tank and engine mounted tank is within a specified limit. This Surveillance has not been adopted in the Monticello ITS. At Monticello, the fuel oil in the day tank and the base tank (i.e.,

the engine mounted tank) is not necessary to meet the 7 day fuel oil requirement.

Monticello Page 3 of 5 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 36 of 48 Attachment 1, Volume 13, Rev. 1, Page 43 of 295

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 37 of 48 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 power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System; and

b. Two emergency diesel generators (EDGs).

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

LCO 3.0A.b is not applicable to EDGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months circuit inoperable. OPERABLE required offsite circuit. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Declare required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from with no offsite power discovery of no offsite available inoperable when power to one division the redundant required concurrent with feature(s) are inoperable. inoperabilityof redundant required feature(s)

AND Monticello 3.8.1-1 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 37 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 38 of 48 AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.3 Restore required offsite 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months circuit to OPERABLE status.

B. One EDG inoperable. B.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE required offsite circuit(s). AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.2 Declare required feature(s), 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from supported by the inoperable discovery of EDG, inoperable when the Condition B redundant required concurrent with feature(s) are inoperable. inoperabilityof redundant required feature(s)

AND B.3.1 Determine OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months EDG is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE EDG.

AND Monticello 3.8.1-2 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 38 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 39 of 48 AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME BA Restore EDG to 7 days OPERABLE status.

C. Two required offsite C.1 Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from circuits inoperable. inoperable when the discovery of redundant required Condition C feature(s) are inoperable. concurrent with inoperabilityof redundant required feature(s)

AND C.2 Restore one required offsite 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months circuit to OPERABLE status.

D. One required offsite --------------------NOTE-------------------

circuit inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.7, AND "Distribution Systems - Operating,"

when Condition 0 is entered with no One EDG inoperable. AC power source to any division.

0.1 Restore required offsite 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months circuit to OPERABLE status.

OR 0.2 Restore EDG to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

E. Two EDGs inoperable. E.1 Restore one EDG to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

Monticello 3.8.1-3 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 39 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 40 of 48 AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, B, AND C, D, or E not met.

F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. Three or more required G.1 Enter LCO 3.0.3. Immediately AC sources inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each required offsite circuit.

SR 3.8.1.2 ------------------------------NOTES-----------------------------

1. All EDG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

2. A modified EDG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

Verify each EDG starts from standby conditions and 31 days achieves steady state voltage ~ 3975 V and

4400 V and frequency ~ 58.8 Hz and

: ;; 61.2 Hz.

Monticello 3.8.1-4 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 40 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 41 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------------NOTES-----------------------------

1. EDG 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 EDG at a time.

4. This SR shall be preceded by and immediately follow, without shutdown, a successful performance of SR 3.8.1.2.

Verify each EDG is synchronized and loaded and 31 days operates for ~ 60 minutes at a load ~ 2250 kW and

2500 kW.

SR 3.8.1.4 Check for and remove accumulated water from each 31 days day tank and base tank.

SR 3.8.1.5 Verify the fuel oil transfer system operates to 31 days transfer fuel oil from the storage tank to the day tanks and from each day tank to the associated base tank.

SR 3.8.1.6 -------------------------------NOTE------------------------------

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. Credit may be taken for unplanned events that satisfy this SR.

Verify automatic and manual transfer of unit power 24 months on a supply from the normal offsite circuit to the alternate STAGGERED offsite circuit. TEST BASIS for each division Monticello 3.8.1-5 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 41 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 42 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 ------------------------------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 plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

2. If performed with EDG synchronized with offsite power, it shall be performed within the power factor limit. 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 EDG rejects a load greater than or equal 24 months to its associated single largest post-accident load, and following load rejection, the frequency is

67.5 Hz.

SR 3.8.1.8 -------------------------------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. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency Core 24 months Cooling System (ECCS) initiation signal, permanently connected loads remain energized from the offsite power system and emergency loads are auto-connected through the time delay relays from the offsite power system.

Monticello 3.8.1-6 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 42 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 43 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9 ------------------------------NOTES-----------------------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. 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. Credit may be taken for unplanned events that satisfy this SR.

3. If part b is performed with EDG synchronized with offsite power, it shall be performed within the power factor limit. 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 EDG operates for ~ 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months s: 24 months

a. For ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 2625 kW and

2750 kW; and

b. For the remaining hours of the test loaded

~ 2250 kW and::;; 2500 kW.

Monticello 3.8.1-7 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 43 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 44 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.10 ------------------------------NOTES-----------------------------

1. This Surveillance shall be performed within 5 minutes of shutting down the EDG after the EDG has operated ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 2250 kW and::;; 2500 kW.

Momentary transients outside of load range do not invalidate this test.

2. All EDG starts may be preceded by an engine prelube period.

Verify each EDG starts and achieves: 24 months

a. In ::;; 10 seconds, voltage ~ 3975 Vand frequency ~ 58.8 Hz; and

b. Steady state voltage ~ 3975 V and::;; 4400 V and frequency ~ 58.8 Hz and::;; 61.2 Hz.

SR 3.8.1.11 -------------------------------NOTE------------------------------

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify each EDG: 24 months

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-Ioad operation.

Monticello 3.8.1-8 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 44 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 45 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ------------------------------NOTES-----------------------------

1. All EDG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of offsite 24 months power signal in conjunction with an actual or simulated ECCS initiation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. EDG auto-starts from standby condition and:

1. Energizes permanently connected loads in ::;; 10 seconds;

2. Energizes auto-connected emergency loads through time delay relays;

3. Achieves steady state voltage ~ 3975 V and::;; 4400 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.

Monticello 3.8.1-9 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 45 of 48

Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 46 of 48 AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 -------------------------------NOTE------------------------------

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced load block 24 months is greater than or equal to the minimum design load interval.

Monticello 3.8.1-10 Amendment No. 146 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 46 of 48

Kewaunee ITS Conversion Database Page 1 of 1 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 47 of 48 Licensee Response/NRC Response/NRC Question Closure Id 1751 NRC Question GMW-005 Number Select Application NRC Question Closure

Response

Date/Time Closure Statement This question is closed and no further information is required at this time to draft the Safety Evaluation.

Response

Statement Question Closure 1/13/2010 Date Attachment 1 Attachment 2 Notification NRC/LICENSEE Supervision Added By Gerald Waig Date Added 1/13/2010 11:13 AM Modified By Date Modified Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 47 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1751 06/03/2010

Kewaunee ITS Conversion Database Page 1 of 1 Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 48 of 48 Licensee Response/NRC Response/NRC Question Closure Id 1761 NRC Question GMW-005 Number Select Application NRC Question Closure

Response

Date/Time Closure Statement This question is closed and no further information is required at this time to draft the Safety Evaluation.

Response

Statement Question Closure 1/13/2010 Date Attachment 1 Attachment 2 Notification Kewaunee ITS Conversion Database Members Added By Gerald Waig Date Added 1/13/2010 11:18 AM Modified By Date Modified Enclosure (2 of 4) Q&A to Attachment 1, Volume 13 (Section 3.8) Page 48 of 48 http://www.excelservices.com/rai/index.php?requestType=areaItemPrint&itemId=1761 06/03/2010

v t e Letter Sequence Other
TAC:ME2139, Deletion of E BAR Definition and Revision to RCS Specific Activity Tech Spec (Approved, Closed)
Initiation Request, Request, Request, Request, Request Acceptance, Acceptance Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement Administration Withholding Request Acceptance Questions 13 January 2010 11 March 2010 Answers Results Approval, Approval, Approval Other: ML093130368, ML102210288, ML102371088, ML102371098, ML102371109, ML102371140, ML102371178, ML102371203, ML102371205, ML102371210, ML102371257, ML102371260, ML102371266, ML102371269, ML102371282, ML102371283, ML102371290, ML102371292, ML102371294, ML102371297, ML102580704, ML102580706, ML102580709, ML102580710, ML102670754, ML102730398, ML102730399, ML103370691, ML110260316
MONTHYEAR2010-07-01 [Table View]

ML102371290

Text

Response

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