GNRO-2018/00013, Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425)
| ML18102B445 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 04/12/2018 |
| From: | Emily Larson Entergy Operations |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| GNRO-2018/00013 | |
| Download: ML18102B445 (607) | |
Text
{{#Wiki_filter:*~Entergy Entergy Operations, Inc. P.O. Box756 Port Gibson, Mississippi 39150 _ Tel: 601-437-7500 Eric A. Larson Site Vice President Grand GulfNuclear Station GNR0-2018/00013 April 12, 2018 10 CFR 50.90 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, -oc 2oss5~0001 .
SUBJECT:
Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425) Grand Gulf Nuclear Station, Unit 1 Docket No. 50-416 *
-ucense-No. -NPF~29
REFERENCE:
NUREG-1434, "Standard Technical Specifications General Electric BWR/6
- Plants," Rev 4, Volume 1, Specifications, April 2012 (NRC Agencywide Documents Access and Management System (ADAMS) Accession No. ML12104A195)
Dear Sir or Madam:
\ -1n accordance with the provisions. of Title to of the Code of Federal Regulations (10 CFR:Part 50.90), "Application for amendment to license, construction permit, or early site permit," Entergy Operations, Inc. (Entergy) is submitting a request for an amendment to the technical specifications (TS) for Grand Gulf Nuclear Station (GGNS), Unit 1.
The proposed amendment would modify the GGNS TS by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specification Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies~" I Attachment 1 provides a description and assessment of the proposed change, the requested confirmation of applicability, and plant-specific verifications. Attachment 2 provides documentation of probabilistic risk assessment (PRA) technical adequacy. Attachment 3 provides the existing TS pages marked to show the prop9sed change. Attachment 4 provides revised (clean) TS pages. Attachment 5 provides the proposed TS Bases changes for information only. Attachment 6 provides a Proposed No Significant Hazards Consideration. Attachment 7 provides a cross reference table that correlates GGNS TS surveillance requirement numbers to the NUREG-1434 (Reference) TS surveillance requirement numbers. Approval of the proposed amendment is requested by April 12, 2019. Once approved, the amendment will be implemented within 90 days following issuance of the amendment.
-GNR0~201 a1ooot3 Page 2 of 3 In accordance with 10 CFR 50.91, "Notice for public comment; State consultation," a copy of this application, with attachments, is being provided to the designated Mississippi Official. No new regulatory commitments are made in this submittal. If you should have any questions regarding this submittal, please contact Douglas Neve - Manager, Regulatory Assurance, at 601-437-2103. I declare under penalty of perjury that the foregoing is true and correct. Executed on the 12th day of April 2018. Sincerely, I I, Eric A. Larson EAL/rn Attachments: 1. Description and Assessment
- 2. Documentation of PRA Technical Adequacy
- 3. Proposed Technical Specification Changes (Mark-Up)
- 4. Revised Technical Specification Pages
-S. -Proposed Technical-Specification "Bases-Changes {Information Only)
- 6. Proposed No Significant Hazards Consideration
- 7. Grand Gulf Nuclear Station (GGNS), Unit 1, TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference cc: with Attachments Mr. Siva Lingam U.S. Nuclear Regulatory Commission Mail Stop OWFN/8 81 11555 Rockville Pike Rockville, MD 20852-2738 cc: without Attachments Mr. Kriss -Kennedy Regional Administrator, Region IV U.S. Nuclear Regulatory Commission
.1600 East Lamar Boulevard Arlington, TX 76011-4511 NRC Resident Inspector Grand Gulf Nuclear Station Port Gibson, MS 39150
GNR0-2018/00013 Page 3 of 3 , Dr. Mary Currier, M.D., M.P.H State Health Officer Mississippi Department of Health P.O. Box 1700 Jackson, MS 39215-1700 Email:mary.currier@msdh.ms.gov
ATTACHMENT 1 to GNR0-2018/00013 Description and Assessment (9 pages)
- Description and Assessment GNR0-2018/00013 1.0 Description The proposed amendment would modify Technical Specifications (TS) by relocating specific surveillance frequencies to a licensee-controlled program with the adoption of Technical Specification Task Force (TSTF)-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to TS Chapter 5.0, Administrative Controls.
The changes are consistent with NRC approved lndustry/TSTF Standard Technical Specifications (STS) change TSTF-425, Revision 3, (Rev. 3) (NRC Agencywide Documents Access and Management System (ADAMS) Accession No. ML090850642). The Federal Register notice published on July 6, 2009 (74 FR 31996) announced the availability of this TS improvement. 2.0 Assessment 2.1 Applicability of Published Safety Evaluation Entergy Operations, Inc. (Entergy) has reviewed the model safety evaluation (SE) provided in Federal Register Notice 74 FR 31996, dated July 6, 2009. This review included the NRC staff's modei SE, TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Revision 1 (NRC ADAMS Accession No. ML071360456). Attachment 2 includes Entergy's documentation with regard to the Grand Gulf Nuclear Station, Unit 1 (GGNS) probabilistic risk assessment (PRA) technical adequacy consistent with the requirements of Regulatory Guide 1.200, Revision 2 (NRC ADAMS Accession No. ML090410014), Section 4.2, and describes any PRA models without NRG-endorsed standards, including documentation of the quality characteristics of those models in accordance with Regulatory Guide 1.200. Entergy has concluded that the justifications presented in the TSTF proposal and the model SE prepared by the NRC staff are applicable to GGNS and justify this amendment to incorporate the changes to the GGNS TS. 2.2 Optional Changes and Variations The proposed amendment is consistent with the STS changes described in TSTF-425, Revision 3; however, Entergy proposes variations or deviations from TSTF-425, as identified below, and include differing TS Surveillance numbers.
\
- 1. The definition of STAGGERED TEST BASIS is being retained in the GGNS TS Section 1.1, "Definitions," because this terminology continues to be used in several SR Frequencies which are not the subject of this amendment request and is not proposed to be changed (e.g., SRs 3.4.4.3, 3.5.1.7, and 3.6.1.6.1 ). This is an administrative deviation from TSTF-42~ with no impact on the NRC staffs model SE dated July 6, 2009 (74 FR 32001 ).
Page 1 of 9
- Description and Assessment GNR0-2018/00013
- 2. GGNS SRs with SR numbers that differ from the corresponding TSTF-425 SRs are administrative deviations from TSTF 425 with no impact on the NRC's model SE dated July 6, 2009 (7 4 FR 32001 ).
- 3. For NUREG-1434 SRs not contained in the GGNS TS, the corresponding mark-ups included in TSTF-425 for these SRs are not applicable to GGNS. This is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
4: Plant-specific SRs 3.4.9.2, 3.4.10.2, 3.6.1. 7.2, 3.6.2.3.2, 3.9.8.2, and 3.9.9.2 are not contained in the mark-ups provided in TSTF-425. These SRs were added to the GGNS TS per License Amendment 202 (NRC ADAMS Accession No. ML15104A623), which implements TSTF-523, Revision 2. TSTF-523 allows the option of relocating the applicable SRs to the Surveillance Frequency Control Program (SFCP). For these and other plant-specific SRs identified in Attachment 7 that are not contained in the NUREG-1434 mark-ups provided in TSTF-425, Entergy has determined that the relocation of the frequencies for these GGNS plant-specific SRs is consistent with the intent of TSTF-425, Revision 3, and with the NRC's model SE dated July 6, 2009 (74 FR 32001 ). The subject plant-specific SR frequencies are periodic frequencies and do not meet the scope exclusion criteria identified in Section 1.0, lllntroduction," of the model SE. In accordance with TSTF-425, changes to the frequencies for these SRs would be controlled under the SFCP. The SFCP provides the necessary administrative controls to require that SRs related to testing, calibration and inspection are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to frequencies in the SFCP would be evaluated using the NRC approved methodology and probabilistic risk guidelines contained in NEI 04-10, Revision 1. This deviation from TSTF-425 is consistent with other industry applications adopting TSTF-425 (e.g., Waterford Unit 3 License Amendment 249 - NRC ADAMS Accession No. ML16159A419, Perry Unit 1 License Amendment 171 - NRC ADAMS Accession No. ML15307A349, and Brunswick Units 1 and 2 License Amendments 276 and 304, respectively - NRC ADAMS Accession No. ML17096A129).
- 5. The SFCP is added to TS 5.5.6 and the word "Deleted" is removed instead of adding the program at the end of TS Section 5.5. This change is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001)
- 6. Periodic frequencies associated with GGNS TSs 5.5.7, 5.5.9, and 5.5.13 are included in the scope of this amendment that are not identified for relocation in TSTF-425, Revision 3.
The first paragraph of TS 5.5.7 is revised, in part, as follows (deleted text in strikeout and added text in italics):
" ... required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision Page 2 of 9 - Description and Assessment GNR0-2018/00013 2, except that testing specified at a frequency of 18 months is required at a frequency of 24 months in accordance with the Surveillance Frequency Control Program."
TS 5.5.9.a is revised as follows (deleted text in strikeout and added text in italics):
"Acceptability of new fuel oil for use prior to addition to storage tanks, and acceptability of stored fuel oil every 92 daysat a frequency in accordance with the Surveillance Frequency Control Program, by determining that the fuel oil has:"
TS 5.?.9.c is revised as follows (deleted text in strikeout and added text in italics):
"Total particulate concentration of the fuel oil in the storage tanks is s 2 mg/100 ml when tested every 92 days in accordance with ASTM D-2274-70 at a frequency in accordance with the Surveillance Frequency Control Program."
TS 5.5.13.d.5 is revised, in part, as follows (deleted text in strikeout and added text in italics):
"An assessment of the CRE Boundary will be conducted every 18 monthsat a frequency in accordance with the Surveillance Frequency Control Program."
Entergy has determined that the relocation of the periodic frequencies associated with these specifications are consistent with the intent of TSTF-425, Revision 3, and with the NRC's model SE dated July 6, 2009 (74 FR 32001 ). The subject TS Section 5.5 frequencies are periodic frequencies and do not meet the scope exclusion criteria identified in Section 1.0, "Introduction," of the model SE. These changes are similar to the SR frequency relocation (i.e., TS 6.5.17.d frequency) to the SFCP that the NRC approved for Waterford Unit 3 License Amendment 249 (NRC ADAMS Accession No. ML16159A419). In accordance with TSTF-425, changes to the frequencies for these surveillances would be controlled under the SFCP. The SFCP provides the necessary administrative controls to require that surveillances related to testing, calibration and inspection are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to frequencies in the SFCP would be evaluated using the NRC approved methodology and probabilistic risk guidelines contained in NEI 04-10, Revision 1.
- 7. Entergy proposes combining SR 3.3.1.1.21 and SR 3.3.1.1.22 with SR 3.3.1.1.13 and SR 3.3.1.1.15, respectiv~ly because the proposed changes to SRs 3.3.1.1.21 and 3.3.1.1.22 and the changes to SRs 3.3.1.1.13 and 3.3.1.1.15 result in the two pairs of SRs being the same. SRs 3.3.1.1.21 and 3.3.1.1.22 were added to the TS pursuant License Amendment 188, dated March 28, 2012 (NRC ADAMS Accession No. ML120400319), as part of the power range neutron monitoring system digital upgrade, both with a frequency of 24 months. Later, the frequency of SRs 3.3.1.1.*13 and 3.3.1.1.15 was modified from 18 months to 24 months pursuant License Amendment 197, dated December 26, 2013 (NRC ADAMS Accession No. ML13343A109), to support operation with a 24 month fuel cycle. Entergy proposes Page 3 of 9
- Description and Assessment GNR0-2018/00013 the deletion of SRs 3.3.1.1.21 and 3.3.1.1.22 rather than maintaining redundant TS SRs that accomplish the same function. Also, resultant changes are made to the SR references associated with Function 2.e in Table 3.3.1.1-1 as shown in the markup of the TS page (Attachment 3). In addition, as a result of the power range neutron monitoring system digital upgrade approved in License Amendment 188, TS 3.3.1.3 was deleted. Therefore, TS Pages 3.3-13a and 3.3-13b are being removed.
Combining SR 3.3.1.1.21 with SR 3.3.1.1.13 and SR 3.3.1.1.22 with SR 3.3.1.1.15 and removing Pages 3.3-13a and 3.3-13b does not alter the intent of the current SRs nor does the change have an adverse impact on the proposed amendment. This change is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (7 4 FR 32001 ).
- 8. In the process of incorporating SR reference changes to Function 2.e in Table 3.3.1'.1-1, several Functions have been moved to the following pages and footnotes re-annotated, adding the appropriate footnote(s) at the bottom of each page per the guidance of Section 2.1.9 of the TSTF-GG-05-01, Writer's Guide for Plant-Specific Improved Technical Specifications, June 2009 (ISTS Writer's Guide), consistent with NUREG-1434 Table 3.3.1.1-1 format, as shown in the markup of the TS page (Attachment 3). These proposed formatting changes do not alter any technical content on the associated pages and therefore, are considered an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
- 9. NRC letter dated April 14, 2010 (NRC ADAMS Accession No. ML100990099),
provides a change to an optional insert (Insert #2) to the existing TS Bases to facilitate adoption of the Traveler. The TSTF-425 TS Bases insert states the following:
"The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program."
This statement only applies to frequencies that have been changed in accordance with the SFCP and does not apply to frequencies that are relocated but not changed. Consistent with NUREG-1434, Revision 4 (NRC ADAMS Accession No. ML12104A195), Entergy has replaced the TSTF-425 TS Bases Insert #2 with the following variations based on the context of the specific Bases: Individual SR Bases -
"The Surveillance Frequency is controlled under the Surveillance Frequency Control Program."
Multiple SR Bases -
"The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program."
SR Bases containing additional frequencies not controlled in the SFCP - Page 4 of 9
- Description and Assessment GNR0-2018/00013 "The time interval based Surveillance Frequency[ies] is[are] controlled under the Surveillance Frequency Control Program."
SR Bases based on TSTF-523 -
"The Surveillance Frequency is controlled under the Su-rveillance Frequency Control Program. The Surveillance Frequency may vary by location susceptible to gas accumulation."
This administrative deviation from TSTF-425 does not alter the intent of the proposed amendment and does not impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
- 10. Due to the relocation of SR frequencies and replacing them with "In accordance with the Surveillance Frequency Control Program," there are multiple SRs that moved to the next page requiring further formatting as identified in the markup of the TS pages (Attachment 3). The following new pages are added as a result of these formatting revisions:'pages 3.1-24, 3.2-3, 3.4-18a, 3.5-Sa, 3.6-23a, 3.7-16, 3.9-11a, and 5.0-16b. Additionally, minor formatting errors have also been corrected as identified in the markup of the TS pages (Attachment 3). For examples; deletion of unnecessary use of the article "the" in several SRs in accordance with Section 3.1.1.e of the ISTS Writer's Guide; capitalization of "NOTE" and "MODE" as applicable in accordance with Section 3.3.2 of the ISTS Writer's Guide; and aligning the Frequency for several SRs to align with the SR text consistent with NUREG-1434 and in accordance with Section 2.5 of the ISTS Writer's Guide. The following summarizes the formatting corrections:
TS Page No. Format Correction 3.1-22 SR 3.1.7.3- add period 3.1-23 SR 3.1.7.7 Freq. - add line space 3.3-53a SR 3.3.6.1.9 - delete article "the" and change "Main Steam Isolation Valves" to lower case SR 3.3.6.1.10 - change NOTE (h) to Footnote (h), delete article "the" and change Upper Containment Pool to lower case 3.3-61 SR 3.3.6.2. 7 - change "Secondary Containment" to lower case
. 3.3-69 Header- Change title to "SPMU System Instrumentation" and number to "3.3.6.4" to reflect the correct TS title and number 3.4-18 ACTION F - Change "Mode" to "MODE" in Required Actions F.1 and F.2 3.4-23 Remove blank row 3.4-27 SR 3.4.11.1 - change "Effective Full Power Year" to lower case 3.4-28 SR 3.4.11.2 - delete Effective Full Power Year and parentheses ( )
3.5-4 SR 3.5.1.4 - Change column titles from all capitalization to initial capitalization Page 5 of 9
- Description and Assessment GNR0-2018/00013 TS Page No. Format Correction 3.5-5 SR 3.5.1.8 - Capitalize NOTE 3.5-9 SR 3.5.2.5 - Change column titles from all capitalization to initial capitalization 3.6-14 SR 3.6.1.3.1 - Separate Note 2 into three notes, Notes 2, 3, and 4; delete the lead-in "Also," in proposed Note 3; and delete article "the" in proposed Note 4 3.6-16 SR 3.6.1.3.5 - Capitalize NOTE 3.6-17 SR 3.6.1.3.9 Freq. -Align frequency with SR text 3.6-23 SR 3.6.1. 7.1 - Add line space between Notes 1 and 2; change Required to lower case SR 3.6.1.7.5 Freq. - Underline conjunction "AND" 3.6-34 SR 3.6.2.4.4 - Move SR number to align with Note; streamline the lead-in to the Note from, "The requirements of this SR are not..." to "Not..." consistent with NUREG-1434, Example 1.4-6 3.6-48 SR 3.6.4.2.1 Freq. - Align frequency with SR text 3.6-53 SR 3.6.5.1.1 1st Freq. - Change "2" to "two" SR 3.6.5.1.1 3rd Freq. - delete "that;" delete several uses of article "the;" and delete period at the end of the frequency 3.6-60 SR 3.6.5.3.1 - Change "NOTE" to "NOTES;" separate Note into three notes, Notes 1, 2, and 3; delete the lead-in "Also," in proposed Note 2; delete article "the" in proposed Note 3; and capitalize MODES 3.7-3 ACTION F - Change "Mode" to "MODE" in Required Actions F.1 and F.2 .
3.9-12 Header - Change title to "RHR - Low Water Level" and number to "3.9.9" to reflect the correct TS title and number 3.10-25 SR 3.10.9.1 - change "Suppression Pool" to lower case SR 3.10.9.2 - change "Reactor Steam Dome" and "PSIG" to lower case SR 3.10.9.3 - change "Upper Containment Pool" and "Suppression Pool" to lower case SR 3.10.9.4 - change "Upper Containment Pool" to lower case 5.0-14a 5.5.10 - move text to page 5.0-15 and delete page 5.0-14a 5.0-16 Change double line to single line and add "( continued)" below the line 5.0-16a 5.5.13 - change "Total Effective Dose Equivalent" to lower case 5.5.13.c - initial capitalize "Guide" 5.0-16b Title - delete "(continued)" Page 6 of 9
- Description and Assessment GNR0-2018/00013 The formatting changes, as summarized herein and identified in the markup of the TS pages (Attachment 3), are administrative deviations from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
- 11. The SR row associated with SR 3.6.1.9.2 is removed because the associated SR has been deleted in a previous license amendment and is no longer needed.
Subsequent SR is renumbered. fn addition, TS pages 3.3-74, 3.3-76, 3.4-5, 3.6-35/3.6-36, 3.8-17, and 3.8-25 are deleted because the information on these pages was deleted in previous license amendments and, as a result, the pages are no longer needed. As a result, a note is added in the footer of the preceding pages, as applicable, to state the next page number. This eliminates the need to renumber the . subsequent pages. TS page 3.3-75 is renumbered to page 3.3-74. Deleting the SR rows and unnecessary pages does not have an adverse impact on the proposed amendment. These formatting changes do not alter the technical content or the way the TSs are applied, and are administrative deviations from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
- 12. Logical connector "AND" is added to SR 3.2.2.2 frequencies to separate them consistent with Section 1.2, "Logical Connectors," and similar to SR 3.1.7.5 frequencies. The logical connectors were inadvertently omitted in License Amendment 191 (NRC ADAMS Accession No. ML121210020). SR 3.2.2.2 was added to the GGNS TSs as part of the extended power uprate. As identified in Section 4.1.8 of Attachment 1 to the GGNS extended power uprate LAR (NRC ADAMS Accession No. ML102660403), each Frequency is required as identified with the grammaticar conjunction "and." This proposed formatting change restores the intent of the frequencies. As a result, SR 3.2.2.2 is moved to Page 3.2-3 and the follqwing page is renumbered. In addition, current pages 3.2-4 through 3.2-6 are deleted since the related information was previously deleted in License Amendment 188 (NRC ADAMS Accession No. ML120400319). These formatting changes are administrative deviations from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
- 13. The Frequency of SR 3.4.4.3, SR 3.5.1. 7, and SR 3.6.1.6.1 are revised to capitalize lnservice Testing Program consistent with the intent of TSTF-545, Revision 3, "TS lnservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing," which was adopted in License Amendment 211 (NRC ADAMS Accession No. ML16140A133). Adoption ofTSTF-545 removed the lnservice Testing Program from TS Section 5.5 and added a definition, INSERVICE TESTING PROGRAM, in TS Section 1.1, which included capitalizing existing uses of the term "lnservice Testing Program" throughout the TS. This typographical change is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
- 14. The format of TS 3.7.7, "Main Turbine Bypass System," is revised to be consistent
( with NUREG-1434, Revision 4, TS 3.7.6, "Main TL~rbine Bypass System," in accordance with the ISTS Writer's Guide as shown in the markup of the TS pages (Attachment 3). The bracketed information provided in NUREG-1434, Action A was not intended to be added in it's entirety; rather it was intended to provide a choice of wording based on whether the optional portion of the associated LCO was adopted (e.g., Clinton TS 3.7.6 (NRC ADAMS Accession No. ML052720312)). The format Page 7 of 9
- Description and Assessment GNR0-2018/00013 change does not alter the technical content or the way the TS is applied, and is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
Entergy proposes to relocate surveillance frequencies except those that reference other approved programs, are purely event-driven, are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs, or are related to specific conditions. Entergy considers the differences listed herein to be minor variations or deviations of the type permitted by TSTF-425. Attachment 7 provides a cross-reference between the NUREG-1434 SRs included in TSTF-425 versus GGNS TS. This attachment includes a summary description of the referenced TSTF-425/GGNS TS SRs which is being provided for information purposes only and is not intended to be a verbatim description of the TS SRs. This cross-reference highlights the following:
- NUREG-1434 SRs included in TSTF-425 and corresponding GGNS TS SRs with plant-specific surveillance numbers;
- NUREG-1434 SRs not included in TSTF-425 that meet TSTF criteria for frequency relocation and corresponding GGNS TS surveillances with plant-specific surveillance numbers, as applicable;
- NUREG-1434 SRs included in TSTF-425 that are not contained in the GGNS TS; and
- GGNS plant-specific TS surveillances that meet TSTF criteria for frequency relocation but are not contained in either NUREG-1434 or markups in TSTF-425.
Inclusion of Attachment 7 is provided to assist the NRC staffs review of the proposed amendment and has no impact on the NRC staff's model SE dated July 6, 2009 (74 FR 32001 ). 3.0 Regulatory Analysis 3.1 Applicable Regulatory Requirements A description of the proposed changes and their relationship to applicable regulatory requirements is provided in TSTF-425, Revision 3 and the NRC's model SE published in the Notice of Availability dated July 6, 2009 (7 4 FR 31996). Entergy has concluded that the relationship of the proposed changes to the applicable regulatory requirements presented in the Federal Register notice is applicable to GGNS. 3.2 No Significant Hazards Consideration Entergy Operations, Inc. (Entergy) has reviewed the proposed no significant hazards consideration (NSHC) determination published in Federal Register 74 FR 32000 dated July 6, 2009. Entergy has concluded that the proposed NSHC presented in the Federal Register notice is applicable to Grand Gulf Nuclear Station, Unit 1 and is provided as an 1 attachment to this amendment request, which satisfies the requirements of 10 CFR 50.91 (a). Page 8 of 9
- Description and Assessment GNR0-2018/00013 3.3 Precedent Relocation of surveillance frequencies to a licensee controlled program was approved for multiple licensees including; Cooper Nuclear Station Rer License Amendment No.
258 issued on March 31, 2017 (NRC ADAMS Accession No. ML17061A050), D.C. Cook Units 1 and 2 per License Amendment Nos. 334 and 316, respectively, issued on March 31, 2017 (NRC ADAMS Accession No. ML17045A150), and Brunswick Units 1 and 2 per License Amendment Nos. 276 and 304, respectively, issued on May 24, 2017 (NRC ADAMS Accession No. ML17096A129). 3.4 Conclusion Based on the considerations discussed herein, (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 Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public. 4.0 Environmental Consideration Entergy has reviewed the environmental consideration included in the NRC's model safety evaluation published in the Federal Register on July 6, 2009 (74 FR 32006). Entergy has concluded that the NRC's findings presented therein are applicable to Grand Gulf Nuclear Station, Unit 1, and the determination is hereby incorporated by reference for this application. Page 9 of 9
Attachment 2 to GNR0-2018/00013 Documentation of PRA Technical Adequacy (17 pages)
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- f Does *t.his .- .Proj~ct Report' c:ont_cJfn .any, open assumptio'ns, focludi'.r,g
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- 2 Does this; P.r.oject"Report .supersede *an existing Project Report? (If YES.,
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trra: >e>N~E* F{c:;;QJSI PROJECT REPORT Jijl > .*'.iR,.ci1;Jie~E~~rf-~roJ~ir,ie!Y;#A REVISION STATUS SHEET I Grand Gulf Nuclear Station Report No.: ENTCORPSO-GGNS-01 PRA Technical Adequacy to Support Relocation of Technical Specification Revision: 0 Surveillance Requirements to an Owner Controlled Program Project Report Revision Status: Revision Description 0 04/02/2018 Initial issue Attachment Revision Status: Attachment Attachment No. of Pages Revision No. of Pages Revision No. No. N/A
Grand Gulf Nuclear Station PRA Technical Adequacy to Support GGNS I Relocation of T~chnical Specification Surveillance Requirements to an Owner Controlled Program (TSTF 425)
ENTCORP50-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 4 of 17 TABLE OF CONTENTS
- 1. PURPOSE ............................. ,.................................................................................. 5
- 2. SCOPE ..................................................................................................................... 5 2.1. Surveillance Frequency Change Process ................................................................. 6 2.2. Technical Adequacy of a PRA .................................................................................. 7
- 3. GGNS PRA TECHNICAL ADEQUACY ..................................................................... 8 3.1. Discussion ................................................................................................................ 8 3.2. GGNS Internal Events and Internal Flooding PRA Model ......................................... 9 3.2.1. Plant Changes Not Yet lncorporated .............................................................................................9 3.2.2. Peer Review Facts and Observations (F&Os) ...........................................................................14 3.2.3. Consistency with Applicable PRA Standards ............................................................................. 14 3.3. GGNS Fire PRA Model ............................................................................................ 14 3.4. Identification of Key Assumptions ............................................................................ 15 3.5. External Events and Shutdown Considerations ....................................................... 15
- 4. CONCLUSIONS ......................................................................................................16
- 5. REFERENCES ........................................................................................................16 LIST OF TABLES Table 1 Summary of Plant Changes Not Yet Incorporated in the GGNS PRA ...................... 10
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 5 of 17
- 1. PURPOSE The purpose of this report is to document the technical adequacy of the Grand Gulf Nuclear Station (GGNS) Probabilistic Risk Assessment (PRA) model to support the implementation of the Surveillance Frequency Control Program (SFCP), also referred to as Technical Specifications Initiative 5b (Reference 1). GGNS will follow the guidance provided in NEI 04-10, Revision 1 (Reference 2), in evaluating proposed surveillance test interval (STI) changes (also referred as "surveillance frequency" changes).
- 2. SCOPE As explained in NEI 04-10, the Technical SpecifiGations Initiative 5b uses a risk-informed, performance based approach for establishment of the surveillance frequencies, where PRA methods are used to determine the risk impact of the revised intervals. The PRA technical adequacy is addressed through NRC Regulatory Guide (RG) 1.200 (Reference 3), which references the ASME/ANS PRA standard, RA-Sa-2009 (Reference 4 ), for internal events at power. Risk impacts associated with fire, seismic, external events, and shutdown activities may be considered quantitatively or qualitatively.
NEI 04-10 guida11ce includes the five key safety principles described in RG 1.174 (Reference 5), which are followed as part of this risk-informed Technical Specification Interval change program. The five key safety principles are:
- 1. Change meets current regulations unless it is explicitly related to a requested exemption or rule change
- 2. Change is consistent with defense-in-depth philosophy
- 3. Maintain sufficient safety margins
- 4. Proposed increases in core damage frequency (CDF) or risk are small and consistent with the Commission's Safety Goal Policy Statement
- 5. Use performance-measurement strategies to monitor the change The GGNS PRA model Revision 4a is the current model of record for GGNS (Reference 6).
This model and its technical content was constructed and documented to meet the ASME/ANS PRA standard (Reference 4). The PRA model quantification methodology used at Entergy Operations, Inc. (Entergy), nuclear sites is common and well-known to the industry. Entergy's approach for maintaining, updating and documenting the PRA models at all Entergy nuclear sites is controlled in the fleet procedures. These procedures are consistent with the guidance of the ASME/ANS PRA standard (Reference 4). The procedural process is comprehensive and detailed, which in turn provides the basis for establishing and maintaining the technical adequacy of the models, as well as ensuring the models reflect the as-built, as-operated plant configuration of the sites. In addition, self-assessments and independent peer reviews are also utilized by Entergy, which reassures the confidence in the approach and overall adequacy of the models against the recognized industry sta.ndards and methodologies.
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 6 of 17 Sections 2.1 and 2.2 describe the general change process and PRA adequacy requirements, respectively, required to support the Initiative Sb. Section 3 documents the technical adequacy of the GGNS PRA model specifically. 2.1. Surveillance Frequency Change Process NEI 04-10 describes the required steps to be followed to adjust an STI. A summary i~ presented below. *
- Once the STI requiring adjustment is selected, NRC regulatory commitments are collected and reviewed. If any prohibitive commitments are identified, such are examined to determine if the commitment can be changed. If there are no prohibitive commitments, or the commitments may be changed using a commitment change process based on NRC endorsed guidance, then evaluation of the STI revision proceeds. If a regulatory commitment exists and the commitment change process does not permit the change, then the STI revision is not implemented (NEI 04-10, Steps 0-4 (Reference 2)).
- The PRA technical adequacy is evaluated using guidance from RG 1.200 (Reference 3).
The RG addresses the need to evaluate important assumptions that relate to key modeling uncertainties (such as reactor coolant pump seal models, common cause failure methods, success path determinations, human reliability assumptions, etc.). Further, the RG addresses the need to evaluate parameter uncertainties and demonstrate that calculated risk metrics (i.e., CDF and large early release frequency (LERF)) represent mean values. The identified "gaps" to Capability Category II requirements from the endorsed PRA standards in the RG and the identified key sources of uncertainty serve as inputs to identifying appropriate sensitivity cases (NEI 04-10, Step 5 (Reference 2) ).
- Select the revised STI value and revise any changes to the test strategy (NEI 04-10, Step 6 (Reference 2) ).
- Qualitative considerations or qualitative analyses are developed for the STI revision.
Qualitative considerations include surveillance test and performance history, past industry and plant-specific experience, impact on defense-in-depth protection, among other considerations (NEI 04-10, Step 7 (Reference 2)).
- Perform quantitative and/or qualitative PRA assessments. Steps 8 through 12 in NEI 04-10 (Reference 2) provide details regarding the use of PRA for evaluating the STI. The use of the PRA includes: determining if the structures, systems, and components (SSCs) in question are modeled in the PRA, whether the SSCs or operator actions can be modeled (and make changes to the model if possible) or not, perform qualitative assessments as needed, evaluate total and cumulative effect on CDF and LERF, and perform sensitivity studies as needed.
- The results and proposed STI changes are documented and summarized for consideration by the Integrated Decision-making Panel (IDP). The IDP is usually comprised of the site Maintenance Rule expert panel, a surveillance test coordinator and a subject matter expert. The IDP approves or rejects the STI changes (with the possibility of adjustments if applicable). If the IDP approves the STI changes, these are documented and implemented. The IDP is also responsible for reviewing the
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 7 of 17 performance monitoring results and providing feedback if the STI changes, once implemented, result in unsatisfactory performance (NEI 04-10, Steps 16-20 (Reference 2)). 2.2. Technical Adequacy of a PRA As previously discussed, NEI 04-10 (Reference 2) endorses the guidance of the NRC Regulatory Guide 1.200 (Reference 3) for the PRA technical adequacy determination. For the purposes of this report, Section 4.2 of RG 1.200 is used in support of Initiative 5b licensee applications. It is important to note that the scope of Initiative 5b applications is broad, and PRA assessments needed for each application vary from application to application. The following requirements are noted in Section 4.2 as necessary to demonstrate that the technical adequacy of the PRA is of sufficient quality to support the application submittal:
- 1. To address the need for the PRA model to represent the as-designed or as-built, as-operated plant.
- 2. Identification of permanent plant changes (such as design or operational practices) that have an impact on those SSCs modeled in the* PRA but have not been incorporated in the baseline PRA model. If a plant change has not been incorporated in the PRA, the licensee provides a justification of why the change does not impact the PRA results used to support the application. This justification should be in the form of a sensitivity study that demonstrates the accident sequences or contributors significant to the application decision were not adversely impacted (remained the same).
- 3. Documentation that the parts of the PRA required to produce the results used in the decision are performed consistently with the standard as endorsed in the appendices of the RG. If a requirement of the standard (as endorsed in the appendix to the RG) has not been met, the licensee is to provide a justification of why it is acceptable that the requirement has not been met. This justification should be in the form of a sensitivity study that demonstrates the accident sequences or contributors significant to the application were not impacted (remained the same).
- 4. A summary of the risk assessment methodology used to assess the risk of the application, including how the base PRA model was modified to appropriately model the risk impact of the application and results. (Note that this is the same as that required in the application-specific regulatory guides.) *
- 5. Identification of the key assumptions and approximations relevant to the results used in the decision-making process. Also, include the peer reviewers' assessment of those assumptions. These assessments provide information to the NRC staff in their determination of whether the use of these assumptions and approximations is appropriate for the application, or whether sensitivity studies performed to support the decision are appropriate.
- 6. A discussion of the resolution of the peer review (or self-assessment, for peer reviews performed using the criteria in NEI 00-02) facts and observations that are applicable to the parts of the PRA required for the application. This discussion should take the following forms:
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page' 8 of 17
- a discussion of how the PRA model has been changed,
- a justification in the form of a sensitivity study that demonstrates the accident sequences or contributors significant to the application decision were not adversely impacted (remained the same) by the particular issue.
- 7. The standards or peer review process documents may recognize different capability categories or grades that are related to level of detail, degree of plant specificity, and degree of realism. The licensee's documentation is to identify the use of the parts of the PRA that conform to capability categories or grades lower than deemed required for the given application (Section 1-3 of ASME/ANS RA-Sa-2009 (Reference 4)).
This PRA technical adequacy report addresses the quality of the PRA to support relocation of STI frequencies to a licensee controlled document. There are no STI changes proposed for this Initiative Sb application. Items 3 and 4, above, are addressed when preparing an STI change request and are, therefore, not covered in this report. The remaining items above are discussed in Section 3.
- 3. GGNS PRA TECHNICAL ADEQUACY 3.1. Discussion The GGNS PRA models are controlled in accordance with Entergy procedures consistent with the requirements provided in the ASME/ANS PRA Standard (Reference 4), as previously stated in Section 2. Entergy procedures define the process to be followed to implement scheduled and interim PRA model updates and to control the PRA model files. In addition, the procedur~ also defines the process for identifying, tracking and implementing model changes, and for identifying and tracking model improvements or potential issues that may affect the model.
Model changes t.hat are identified are tracked via model change requests (MCRs), which are entered in the Entergy MCR database. Periodic PRA model updates are typically performed at least once every four years, with the option of extending the frequency for up to an additional two years, such that the total update period does not exceed six years. Extensions are justified by showing that the PRA model continues to adequately represent the as-built, as-operated plant and must be approved by management. The GGNS PRA model Revision 4a was approved in October 2017 (Reference 6). GGNS ., models follow the guidelines of RG 1.200. Section 3.2 discusses the requirements in RG 1.200 to demonstrate PRA technical adequacy as applicable to the current GGNS internal events and internal flooding models. The GGNS PRA model Revision 4a is the baseline model of record as of the completion of the 2017 finding closure independent assessment. No changes have been made to the Revision 4a PRA model of record since the completion of the independent assessment. Refer to Section 3.2.2 herein for further discussion of the 2017 independent assessment. GGNS does not currently have a fire PRA model developed in accordance with NUREG/CR-6850 (Reference 7). Section 3.3 discusses the planned approach for a bounding fire risk evaluation for STI changes in accordance with the guidance of NEI 04-10 (Revision 2).
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 9 of 17 3.2. GGNS Internal Events and Internal Flooding PRA Model 3.2.1. Plant Changes Not Yet Incorporated As discussed in in Section 3.1, an MCR database tracks PRA issues or improvements identified by PRA personnel. The MCR database includes the identification of plant changes that could impact the PRA model. As part of the PRA evaluation for each STI change request, sensitivity cases are expected to be explored for areas of uncertainty associated with unresolved items (peer review Findings for ASME/ANS PRA Standard Capability II or plant changes) that would impact the results of the STI change evaluation, prior to presenting the results of the risk analysis to the IDP. A review of the MCR database for GGNS identified several plant engineering changes (ECs) not yet implemented which may potentially impact the PRA. These are listed in Table 1, along with the corresponding EC and MCR numbers, as well as the potential impact on the PRA model.
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 10 of 17 Table 1. Summary of Plant Changes Not Yet Incorporated in the GGNS PRA Several child ECs were written to address NRC Information Notice 92-18 which describes a condition that results from post fire cable damage affecting an MOV control circuit causing both spurious valve actuation and loss of the torque/limit switch protection potentially causing mechanical failure of the valve. The ECs eliminate this susceptibility by modifying .control circuit wiring or moving the limit and torque switches. This may have an impact on the frequency used for hot shorts in the fire PRA and therefore the following ECs should be reviewed during update of the fire PRA model: GGNS EC 25542, 25112, 25287, 25093, 24337, 26320, 26458, 27411, 27412, The modification is intended for fire MCR- EC 23923 27413, 27414, and 27415. considerations. The potential impact will be GG-4241 (parent) addressed by STI change evaluations performed The 33 valves that require modification are listed below: in accordance with the SFCP. 1B21-F019, 1E12-F003A, 1E12-F004A, 1E12-F006A, 1E12-F008, 1E12-F011A, 1E12-F024A, 1E12-F027A, 1E12-F028A, 1E12-F037A, 1E12-F040, 1E12-F042A, 1E12-F047A, 1E12-F048A, 1E12-F053A, 1E12-F064A, 1E12-F073A, 1E51-F045, 1 E51-F095, 1G33-F034, 1 P41-F001A, 1P41-F005A, 1P41-F006A, 1P41-F007A, 1P41-F014A, 1P41-F016A, 1P41-F018A, 1P41-F068A, 1P41-F237, 1P41-F238, 1 P41-F241, 1P42-F200A, 1 P42-F201A Not all the valves are currently modeled in the PRA. This procedure should be reviewed for impact during the fire PSA model development. EC-25112 addresses non-compliances related to RG 1.189. This EC addresses hot shorts vulnerability which affected breaker control circuitry for circuit breaker 152-1505 which feeds CRD pump motor 1C11C001A. One new 15A fuse and fuse holder replaces the four existing fuses and fuse holders in The modification is intended for fire pump motor switchgear cubicle1A5-05. Although fuses are not directly MCR-GG- considerations. The potential impact will be EC 25112 modeled in the fire PRA model, there is potential that this may impact the 4274 addressed by STI change evaluations performed likelihood of a fire occurring in that fire area (located in Room OC202, Fire Zone in accordance with the SFCP. OC202). This procedure should be reviewed for impact during the fire PSA model development. EC-24584 requires that the following changes be made to Procedure 05-1 MCR-GG- The modification is intended for fire EC 24584 11-1: considerations. The potential impact will be 4275
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 11 of 17 Procedure 05-1-02-11-1 (Ref. 2.3.7.9) shall be revised to remove the 'IF' from addressed by STI change evaluations performed Step 3.3 to ensure MSIV closure. Any action taken in the control room for a in accordance with the SFCP. control room fire should be followed up by an action outside of the control room to ensure success. Additionally, a note should be added that this is an Appendix R credited action. Procedure 05-1-02-11-1 (Ref. 2.3.7.9) shall be revised to include a step to close manual valves 1P44-F448 (SSW/PSW X-TIE MAN ISOL) and 1P44-F449 (SSW/PSW X-TIE MAN ISOL) within 24 hours to terminate SSW flow diversion. Procedure 05-1-02-11-1, Attachment XVI (Ref. 2.37.9) shall be revised to add the following guidance: Spurious breaker trip and loss of local diesel generator indication, which may result from fire-induced cable damage, can be overridden by opening test switch TS-2 at panel 1H22-P113 in Fire Zone 10310. This procedure should be reviewed for impact during the fire PSA model development. As of June 2017, BWROG EPC Revision 3 has not been implemented at GGNS. Therefore, this As necessary, revise PRA models to account for post-Fukushima EOP MCR was not incorporated into PSA Revision 4a. MCR-GG-changes. Refer to BWROG letter BWROG_EPC_12C27.PDF for discussion of 4690 EPG-SAG changes. The potential impact will be addressed by STI change evaluations performed in accordance with the SFCP. ECO 57214 revises setpoints for the feedwater system. The RPV Level L9 trip is changed from 56" to 58" and FWLCS INFl-90 setpoint reduced from 13" to The modification involves feedwater setpoint 4". This is to reduce the likelihood of a scram during transients. changes to reduce the likelihood of reactor trip MCR-ECD 57214 during feedwater transients. The potential impact GG-5387 Revise the system notebook and other PSA documents that may have these will be addressed by STI change evaluations setpoints discussed. Review MAAP cases to see if any of them are impacted by performed in accordance with the SFCP. this plant mod and consider rerunning with* revised setpoints or assess impact of this change on the MAAP case(s).
"Loss of 125 VDC Off-Normal Event Procedure" (ONEP) 05-1-02-Vl-19, The modification involves restoration of 125 VDC, Revision 000, is a new ONEP. The ONEP provides directions for Operators to which may impact the likelihood of loss of DC MCR-GG- restore 125 VDC. This impacts the PRA Model in that the restoration of DC 05-1-02-Vl-19 power. The potential impact will be addressed by 6046 Power is an event mitigation action, the implementation of the actions STI change evaluations performed in accordance introduces the potential for human errors, and can initiate an accident. The loss with the SFCP.
of 125 VDC can be caused by a fire, inducing the postulated accident.
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 12 of 17 The modification involves response to electrical New ONEP, 05-1-02-V-18, Electrical System Grounds, provides Operators grounds, which may impact the likelihood of loss MCR-GG- . 05-1-02-V-18 instructions to respond to electrical grounds. This new ONEP provides of power events/initiators. The potential impact 6114 procedural guidance for Operators to respond to a potential initiating event and will be addressed by STI change evaluations likely reduces the HRA. performed in accordance with the SFCP. EC 75259 increases the setpoint for RCIC time delay relays 1E51 K94 and 1E51 K95. These two relays actuate and cause a Group 4 isolation on valid The modification involves the timing for RCIC signals. By increasing the setpoint from 1 second to 10 seconds, the automatic isolation, which may reduce the likelihood for MCR-GG- isolation occurs on an actual condition. This reduces the likelihood of spurious EC 75259 spurious isolation. The potential impact will be 6177 isolation that results from false signals. addressed by STI change evaluations performed in accordance with the SFCP. The EC was developed because of ESF11 lockout and the automatic RCIC isolation. CR-GGN-2017-12612: There is no direction in "Loss of PSW ONEP" about securing an RWCU Pump. This was performed using G33 SOI guidance. A The potential modification involves the response significant improvement of approximately 5# psig rise in PSW header pressure to a loss of plant service water, which may affect MCR-GG- (10% gain) was seen when this action was completed. The "Loss of PSW the human error actions or probability for 05-1-02-V-11 6203 ONEP" needs to be revised. recovery. The potential impact will be addressed by STI change evaluations performed in This may introduce an additional proceduralized operator action to respond to a accordance with the SFCP. partial or total loss of Plant Service Water.
*CR-GGN-2018-0032: The following procedural discrepancies were found in SOI 04-1-01-E12-1, Residual Heat Removal System:
The modification involves the timing for opening of the RHR heat exchanger bypass, which may Interlock-to-open signal for E12-F048A/B, RHR A/8 Heat Exchanger Bypass MCR-GG- EC 31722 affect accident sequence timing. The potential Valve, time is stated as 10.85 minutes. EC 31722 changed the time of this 6204 04-1-01-E12-1 impact will be addressed by STI change interlock from 10.85 minutes to 3.41 minutes. evaluations performed in accordance with the SFCP. This MCR is initiated to potentially revise the RHR System Notebook and applicable portions of the Accident Sequences. CR-GGN-2018-0034: In 05-1-02-IV-1, Control Rod/Drive Malfunctions, step 2.1.1; When restarting CRD after a pump trips it requires to re-energize MCCs The potential modification involves the response 15842 and 16842 if required. IF AN ECCS INITIATION HAS OCCURRED MCR-GG- to a CRD pump trip, which may affect the human THEN THE "CRD AUX OIL PUMPS" MUST BE RESTARTED TO ALLOW THE 6205. 05-1-02-IV-1 error actions or probability for recovery. The MAIN CRD PUMP TO START. Procedure does not cover this action.
-6206, 04-1-01-E12-1 potential impact will be addressed by STI change -6207 evaluations performed in accordance with the CR-GGN-2018-0040: Attachment IX, Recovery from a Division 1 ECCS SFCP.
Initiation Signal, in SOI 04-1-01-E12-1, does not contain a step to re-energize MCC 15842.
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 13 of 17 CR-GGN-2018-0041: Attachment IX, Recovery from a Division 2 ECCS Initiation Signal, in SOI 04-1-01-E12-1, does not contain a step to re-energize MCC 16842. The MCRs are written in advance of a procedure revision that would direct Operators to restart CRD AUX OIL PUMP prior to restarting the associated CRD Pump.
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 14 of 17 3.2.2. Peer Review Facts and Observations (F&Os) The GGNS PRA model has undergone several peer reviews which document the motjel quality and identify any areas with potential for improvement. The following assessments have been performed and documented for the GGNS model:
- A peer review certification (Reference 8) of the GGNS PRA model Revision 1 was conducted by the Boiling Water Reactor Owners Group (BWROG) in October 1997 (Reference 9). The peer review concluded that the GGNS PRA was sufficient to support meaningful rankings for the assessment of SSCs and judged capable of supporting absolute risk determination to support applications.
- A full-scope industry peer review of the GGNS PRA model Revision 4 (Reference 10) was conducted by the BWROG September 21-25, 2015 (Reference 11 ). This peer review documented sixty-six (66) new F&Os including thirty-nine (39) Findings, twenty-six (26) Suggestions, and one (1) Best Practice. The peer review concluded that the GGNS PRA substantially (approximately 85% of the Supporting Requirements) met the ASME/ANS PRA standard at Capability Category II or better. This model revision was not issued for use because the PRA model was updated to Revision 4a to resolve the F&Os.
The GGNS PRA internal events model Revision 4a was approved in October 2017 (Reference
- 6) and incorporated changes, as applicable, to support the resolutions of the 2015 peer review findings. The 2015 peer review findings and the associated resolutions are documented in the MCR database and a resolution summary report (Reference 12). The full-scope peer review findings from 2015 were closed by an independent assessment conducted August 23-31, 2017.
The closure assessment was conducted in accordance with Appendix X to NEI 05-04 (Reference 13) utilizing the conditions of acceptance stated in an N~C letter to the Nuclear Energy Institute dated May 3, 2017 (Reference 14 ). The independent assessment is documented in the closure report (Reference 15) and concluded that none of the changes made to the GGNS PRA were considered a PRA upgrade or use of a new PRA method. 3.2.3. Consistency with Applicable PRA Standards The GGNS PRA model Revision 4a meets the ASME/ANS PRA standard (Reference 4) Capability Category II of the Supporting Requirements (SRs). Current Entergy PRA documentation includes a self-assessment that documents how each high-level requirement (HLR) and SR are met. The latest full-scope peer review for GGNS was conducted in September 2015 (Reference 11) using the ASME/ANS PRA standard (Reference 4 ). Since then, model Revision 4a (Reference 6), to address the peer review findings and incorporate some elements of FLEX, was completed which ensured all the F&Os from the peer review were addressed. All the F&Os are captured and documented in the MCR database and the resolution summary report (Reference 12). No finding level F&Os remain open for the GGNS internal events and internal flooding PRA. 3.3. GGNS Fire PRA Model Grand Gulf Nuclear does not currently have a fire PRA model. Therefore, a bounding fire risk evaluation, based on information from the Individual Plant Examination of External Events
ENTCORP50-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy . Page 15 of 17 (IPEEE, Reference 16) and other available insights for fire risk, will be performed for STI changes in accordance with the guidance of NEI 04-10 (Revision 2). 3.4. Identification of Key Assumptions The Initiative 5b is a risk-informed process which uses PRA model results to support a proposed STI change. The IDP uses the PRA results as an input to decide whether an STI change is warranted. The methodology recognizes that a key area of uncertainty for this application is the standby failure rate utilized in the determination of the STI extension impact. Therefore, the methodology requires the performance of selected sensitivity studies on the standby failure rate of the component(s) of interest for the STI assessment. Any additional sensitivity studies identified for specific STI changes are also required per NEI 04-10, Revision 1 (Reference 2). Therefore, results of the standby failure rate sensitivity study plus the results of any additional sensitivity studies identified during the performance of the reviews of gaps and open items as summarized in Sections 3.2 and 3.3 herein, will be documented and included in the results of the risk analysis submitted to the IDP. 3.5. External Events and Shutdown Considerations The NEI 04-10 (Reference 2) methodology allows for STI change evaluations to be performed in the absence of quantifiable PRA models for all external hazards and shutdown. For those cases where the STI cannot be modeled in the plant PRA, or where a particular PRA model does not exist for a given hazard group, a ql:lalitative or bounding analysis is performed to provide justification for the acceptability of the proposed test interval change. External hazards were evaluated in the GGNS IPEEE submittal (Reference 16) in response to the NRC IPEEE Program (Reference 17). The IPEEE Program was a one-time review of external hazard risk and was limited in its purpose to the identification of potential plant vulnerabilities and the understanding of associated severe accident risks. GGNS does not have a PRA model or applications associated with external hazards such as seismic, high wind or external flooding, and quantitative results cannot be provided to support this STI *effort. Therefore, a qualitative or bounding approach will be used to assess external event hazard risk at GGNS for STI changes. Because GGNS does not have external hazards or RG 1.200 conforming shutdown PRA models, external hazards and shutdown screening evaluations are performed for STI changes in accordance with the guidance of NEI 04-10, Revision 1 (Reference 2). The GGNS shutdown safety program developed to support implementation of NUMARC 91-06 (Reference 18) is used for the shutdown risk evaluation, or an application-specific shutdown analysis may be performed for STI changes in accordance with the guidance of NEI 04-10, Revision 1 (Reference 2).
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 16 of 17
- 4. CONCLUSIONS The information presented in herein demonstrates that the GGNS PRA technical adequacy and capability evaluations, as well as the maintenance and update processes conform to the ASME/ANS PRA Standard, which satisfies the guidance of RG 1.200, Revision 2 (Reference 3).
- 5. REFERENCES
- 1. TSTF-425, "Technical Specification Task Force - Relocate Surveillance Frequencies to Licensee Control- RITSTF Initiative 5b", Revision 3, March 2009.
- 2. NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b. Risk-Informed Method for Control of Surveillance Frequencies", Revision 1, April 2007.
- 3. Regulatory Guide 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities", Revision 2, March 2009.
- 4. ASME/ANS RA-Sa-2009, "Addend to ASME/ANS RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications", February 2, 2009.
- 5. Regulatory Guide 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-
*informed Decisions on Plant-Specific Changes to the Licensing Basis", Revision 2, May 2011.
- 6. PSA-GGNS-01, "Grand Gulf Nuclear Station Probabilistic Risk Assessment Summary Report", Revision 0, September 2017.
- 7. NUREG/CR-6850 - EPRl-1011089, "Fire PRA Methodology for Nuclear Power Facilities",
August 2005.
- 8. "BWROG PSA Peer Review Certification Implementation Guidelines," Revision 3, January 1997.
- 9. BWROG/PSA-9707, "Grand Gulf Nuclear Station PSA Peer Review Certification Report,"
October 1997.
- 10. RSC 14-15/PSA-GGNS-01-QU, "Grand Gulf Nuclear Station Probabilistic Risk Assessment Quantification, Sensitivity, and Uncertainty Analysis Work Package" Revision 0, August 2015.
- 11. "Grand Gulf Nuclear Station PRA Peer Review Report Using ASME/ANS PRA Standard Requirements (Internal Events and Internal Flooding at Power)", February 2016.
- 12. PSA-GGNS-01-FNO-RES, "Resolution of GGNS PRA Peer Review Facts and Observations", Revision 0, September 2017.
ENTCORPSO-GGNS-01, Rev. 0 GGNS PRA Technical Adequacy Page 17 of 17
- 13. NEI 05-04/07-12/12-06 Appendix X, "Closeout of F&Os", March 2017 (NRC ADAMS Accession No. ML16158A035).
- 14. Letter from J. Giitter (NRC) & M. Ross-Lee (NRC) to G. Krueger (NEI), "U.S. Nuclear Regulatory Commission Acceptance on Nuclear Energy Institute Appendix X to Guidance 05-04, 07-12, AND 12-13, Close-Out of Facts and Observations (F&Os)", May 3, 2017 (NRC ADAMS Accession No. ML17079A427).
- 15. ENT#GG052-REPT-01, "Grand Gulf Nuclear Station Probabilistic Risk Assessment Peer Review Findings Closure", Revision 0, September 2017.
- 16. GGNS-94-0054, "Grand Gulf Nuclear Station Engineering Report for Individual Plant Examination of External Events- Summary Report", Revision 1, November 1995.
- 17. Generic Letter 88-20, "Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities -10CFR 50.54(f), Supplement 4", June 1.991.
- 18. NUMARC 91-06, "Guidelines for industry actions to assess shutdown management",
December 1991.
Attachment 3 to GNR0-2018/00013 Proposed Technical Specification Changes (Mark-up) (173 pages)
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Control Rod OPERABILITY 3 .1. 3 =SLJ=R=V=E=IL=L=A~NC=E==R=EQ=U=l=RE=M=E=N=TS=== ============r=========~ - SURVEl LLANCE FREQUENCY SR 3.1.3.1 Determine the position of each coritp~l rocJ .. - SR 3.1:.3.2 Deleted SR 3.1.J.3 - - - - - M - - - - - - - - * - - - - NOTE - - - - - - - - * - -- -: -:, :': "-: ~ - . Not required to be performed until<~t -d'~fs after the control rod is withdrawn )pt!'_,* : THERMAL POWER is greater than the LPSP :c;ff:. the RPCS. .
- - - - . - - - - - - - ... - - - - - - - - - - - - - .... - - -- - """.* ~* .~ "':" *~*.'*-:*:*.~*.~*.. ..: ..... *. ~ :
Insert each wi Uidrawn control rod a,t T¢A:~f one notch. SR 3.1.3.4 Verify each cor.trol rod scram timf: ft-t>rn: ful 1 y withdrawn to notch position 13 ts:.
*wJ:th:acc-ord:anc.e
*' :tn'
~ 7 seconds. *
.. ~tt1::t:Jt,:
.'SR .*1~ L. 4'.,'3\ -'ifrld
.-SR 3~1.4\Jr lnaccordance with the Surveillance Frequency Control ,
Program ,* .. GRAND GULF 3.1-10 Amendment No. ~~~t~:::t:ee:' Page 1 of 173
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Control Rod Scram Times 3.1. 4 SURVEILLANCE REQUIREMENTS
- ** - - - * - - - -.* - - - - - - - - - - - - - - - - - - ~ - ~ * - - -NOTE- - - - * ~ - - ~ - - .. * - - - - - - - - - - - * - - - - * - * - - * -
- During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.
SURVEILLANC[ FREQUENCY SR 3.1.4.1 Ver;fy each control rod scram time is Prior to -~, within the limits of Table 3.1.4~1 with exceeding reactor steam dome pressure~ 950 psig. 40% RTP after each reactor shutdown
- 2: 120 days SR 3.1.4.2 SR 3.L4.3 Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with any reactor steam dome pressure.
GRAND GULF 3.1-13 Arnend_ment No. ~;,;;U:9, Page 2 of 173
\ ..
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Control Rod Scram Accumulators 3.1.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME
- c. (continued) C.2 Declare the 1 hour associated control rod inoperable.
D. Required Action and D.l ---~~---NOTE--------- associated Completion Not applicable if all Time of Required inoperable control '\ Action B.l or C.l not rod scram met. accumulators are associated with fully inserted control rods.
~~~-~~--~--~--~--~~--
Place the reactor Immediately mode switch in the
\ shutdown position.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3 .1. 5.1 Verify each control rod scram accumulator * -~;:/'~~<*4-*"_.,- - - - - . *
- pressure is::?;. 1520 psig.
'\_}
GRAND GULF 3.] .. ]8 Amendment No. t,m, Page 3 of 173
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Control *Rod Pattern 3.l.6 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE 8.1 -------~NOTE---~----- control rods not in Affected control rods compliance with BPWS. may be bypassed in RACS in accordance with SR 3 . 3.2.I.9 for insert ion only.
) Suspend withdrawal of Immediately control rods.
AND B.2 Place the reactor 1 hour mode switch in the shutdown posit;on. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. I.6. I Verify all OPERABLE control rods comply with BPWS . \.
'-..,)'
GRAND GULF 3.1-20 Amendment No . "fl~~;,~ Page 4 of 173
***r
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Ste* SYSitem*
.3 .* I*~.*7
\ ...
VE!1:,ify:~*11~i.l'~~1e v.p:rume o:e ,~oo.i-0:ro,, perit,;~qqz:a.t~* $d{µti9n _:_is * ~ :4,/2:.00 "*g_~11¢J1$':. ve;{if)_f +/-:E?roP$::r.;,~t:.i:~..r~ qf*. $qclium* pent'~b:o\ti:i:t:e
'§:ql#t<lorrc.:i'$ -*~: *_4,s~F ~h&:* ~, *fs0°F.
¥e:r:i.f ~i SLc *System sabi_sfies *:t:zhtI fo11ow~n:g_,
. <Format: AJ:~a:=J (j;) (E;j *.:,.
42
\.
Ve:t;:bty: _t,he, petcent: weli.gn.t Pf ,so~:+/-vrtc
,pen*~abg'i:a't~. ,in* .soluti,91:i: is ~- ':9.*5%.
'~~1),
92411<;1e, ~tttrin:
**hotiri a:rt:~r
wii-t~i :cfr qprqn,
.Ls .. adae.d* .,to .
'$6J.p.:t:foh AND Once . w+/-:t:"hin .*
i,r hoBi>f~ :aft¢r 1
*solti:tfon* , ,
t'E=ITIP,~:r;a;t:lli:e *;Ls *
?;~'$tpr:~a.- :to
' lit)¥~,- 't
...........................,.::'.Format: M~J~. SR ~ov,rto next paae.. f$qnt:i;hii'¢dt In c3ccordancewithJheSl.irVeillance.FrequentYCcmtrol Ptogtam . _, .< *
?,~t~.22 Page 5 of 173
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SLC System 3.1.7 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.1.7.6 Verify each SLC subsystem manuai,.,p~w~foper~t~p~ ,-_._ ;~t:~s,* and automatic valve in the flow pathtt,aft$>nof. . -- .
-~-----~"!!"!""!"'-.,
locked, sealed, or otherwise secureµ in pd~it,iori,/1s(,irt the correct position. or can be alignedJo\tle position. cprrt:?:~t *- SR 3.1.7.7 Verify each pump develops a flow rcit~ ~ 41;2'.~prn-,af . :'(11:~~cotd~flC~:iJitn a d,scharge pressure ~ 1370 psig. - .. - . )~EflNS~Ryi'CE --
<Format: Add line space> . :)i!WJj~
SR 3.1.7.8 - _*-SR .s:t.7.9 Determine Boron-10 enrichment in a_forn perc:tirt((I;)'.
$~>~;1.7.10 Verify pipir1g between the storage lc:~nk:c!nci,lh~J:,Qo,ii *_ I:Oh¢e~Wi1fiih,24-suction is 'not blocked. ** -
thours after-- -
'-:restt>r~dJo tlmt:it;~}iS- .*
;j(4'.~ 0 f:*_-_ -*.
1n*accordance with
- the Surveil_lance Frequency Control erqgr~m--,
GRAND GULF 3.1-23
.Ne~.~e~e:,is,'.3:.1':_2~;:
". '"*** *.,.. __ * .,*,1 :* ,*
Page 6 of 173
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SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.1.7.9 Determine Boron-1 O enrichment in atom percent (E). Once within 24 hours after boron is added to the solution SR 3.1.7.10 Verify piping between the storage tank and the pump Once within 24 suction is not blocked. hours after solution temperature is restored to
~45°F GRAND GULF 3.1-24 Amendment No.
Next page is 3.1-26 Page 7 of 173
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SDV Vent and Drain Valves
- 3. 1.8 SURVEILLANCE REQUIREMENTS SURV ElLLA NCE FREQUENCY SR 3. J.8.1 ----------------N OTE*----*----*--*--*-w*
Not required to be met on vent and drain valves closed during pcrfoITT1ance of SR 3. l.8.2. Verify each SDV vent and drain valve is open.
.:~J.~.~y$r~------......
SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully dosed and fully open position. SR 3.1.8.3 Verify each SDV vent and drain valve:
- a. Closes ins 30 seconds after receipt of an actual or
/ simulated scram signal; and .
- b. Opens when the actual or simulated scram signal is reset.
In accordance with the Surveillance Frequency Control Progrc1m
- GR.AND GULF Amendment No. ~ , :197 ,
Page 8 of 173
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APLHGR 3.2.l
- 3. 2 POWER DISTRIBUTION LIMI'l'S 3.2.1 Average Planar Linear Heat Generation Rate (APLHGR)
LCO 3.2.l AJl APLHGRs shaJJ be less than or equal to the limits specified in the COLR. APPLICABILITY': THERMAL POWER~ 21.8% RTP. ACTIONS CONDITION REQUIRED ACTION I COMPLETION TIME A. Any APLHGR not within A. l Restore APLHGR(s) to 12 hours limits. within limits.
- 8. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to < 21. 8% RTP
- Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHCRs are less than or equal Once within to the limiLs specified in the COLR. 12 hours after
~ 21. 8% RTF 2-t hours ...*.
~
In accordance with* the Surveillance Frequency Control Pr9gram. .. GRAND GULF 3.2-1 Amendment No. ~ ~ Page 9 of 173
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MCPR 3.~.£ 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Mlnimum Critical Power Ratio (MCPR) LCO 3.2.2 ~11 MCPRs shall b& greater than oc equal to the MCPR operating limits specified in the COLR.
~PPLICABILI'I'Y: 'l'HERMAL POWER ~ 21. 8 % RTP.
AC TI CNS CONDITION REQUIRED AC'l'ION COMPLE'I'ION 'l'IME A. Any MCPR not ~ithin A.l Restore MCPR(s) to 2 hours limits within limits.
- 8. Required Action and B.1 Reduce THERMAL POWER 11 hours
.,associated Completion to < 21. 8go R'l'P.
Time not m~t. SURVEILLANCE REQUIREMENTS SURVEILL~NCE .FREQUE:NCY SR 3.2.2.1 Verify all MCPRs are greater than or equa~ Cnce within to the limits ~pecified in the COLR. 12 hours after
?: 21. 8% RTP AN~
SR ~.2.2.2 Dete£mjne the MCPR limit~. 0!1CC:{*t~1thl.h* .
.* . 72.:. hcrut*s, ~fte,r.
*.*ec:idJt tdl1lpT~ti*1;m
- of SR :-3 *~i. 'L'l
.-e~c'h .c;ornp'letion of SR J./L 4:. 4 *
,:GMWD' GULF 3.2-2
')"*-~---~,. format: Move SR row to new Page 3.2-3. Page 10 of 173
<Insert Page 3.2-3>
MCPR 3.2.2 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours after each completion of SR 3.1.4.1 Once within 72 hours after each completion of SR 3.1.4.2 Once within 72 hours after each completion of SR 3.1.4.4 GRAND GULF 3.2-3 Amendment No. Page 11 of 173
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LHC::R 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.~.3 Linear Heat Generation Rate (LHGR) LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR. APPLICABILITY: THERMAL POWER~ 21.8% RTP. ACTIONS CONDITION REQUIRED ACTION COMP LET ION TIME A. Any LHGR not within A.1 Restore LHGR(s} to 2 hours lirni ts within limits. B. Required Action and .B .1 Reduce THERMAL POWER -4 hours associated Completion ta< 21.Bti RTP. Time not met . . SURVEILLANCE REQUIREMENTS SURVEILLANCE Ff..EQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to Once within the limits specified in the COLR. 12 hours after
~ 21.R% RTP ;~:
}~*
GRAND GULF 1.2--3.~* Amendment No. l'i20}. I~~, Page 12 of 173
0
*Delete~:
. 3'..i.:4 Page 13 of 173
,Df!l:*e,~ea
***t.*~c4 l
Page 14 of 173
Page 15 of 173
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RPS Instrumentation 3.3.1.1 SURVETLLANCE REQUTREME'.N'I'S
NOTES--- --------------------------------
- 1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains RPS triF capability.
SURVEILLANCE FREQUENCY SR 3.3.l.l.l Perform CHANNEL CHECK.
.-----------------NOTF.-------------------
Not required to be performed until 12 hours after THERMAL POWER~ 21.8% RTP. Verify the absolute difference between the average power range monitor (APHM) channe1s and the calculated power
~ 2!f. RTP while operating at ~ 21.B~. RTP.
SR 3. 3. L 1. 3 ------------------NOTE------------------- Not reguired to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2. Perfor-m CHANN1:;L FUNCTIONAL TEST. SR 3
- 3. 1
- 1 . 4 Perform CHANNEL FUNCTIONAL TBST.
In accordance with the Surveillance Frequency Control. Prag rc:1111 ... GRAl\'D GUL!-' 3.3-3 Amendment No. f2Qy ~ l Page 16 of 173
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RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.1.5 Deleted SR 3.3.1.1.6 Deleted . SR 3.3.1.1.7 Ca l i br a t e th e l oc a l pow e r r ang e mo ni to r s . 2OOo
- Mt~ o/q:
SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.1.1.9 Calibrate the trip units. (continued) GRAND GULF 3.3-4 Amendment No. ~ * -4++ ' Page 17 of 173
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RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued} SURVEILLANCE FREQUENCY SR J.3.1.1.10 ------------------NOTES------------------
- 1. Neutron detectors are excluded.
- 2. For Function 2.a, noc required to be performed when entering MOUE 2 from MODE l until 12 hours after entering MODE 2.
- 3. For Function 2.d, APRM recirculation flow transmitters are excluded.
Perform CHANNEL CALIBRATION. G~ANO GULF 3.3-4a Page 18 of 173
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RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued'). SURVE I.LLANCE FREQUENCY SR 3 . 3 . 1 . 1 , 11 Perform CHANNEL FUNCTIONAL TEST. .*.~:.*. SR 3. 3. 1. 1. 12 ------------------NOTES-~---------------
- 1. Neutron detectors are excluded.
- 2. Fa:r IRMs, ~not required to be performed when entering MOPE 2 from MODE l until 12 hours after entering MODE 2.
Perform CHANNEL CALIBRATION. SR 3.3.1.1.13 Perfor~ LOGIC SYSTEM F~NCTIONAL TEST. ,,2.4'* SR 3.3.1.1.14 Verify Turbine Stop Valve Closure, Trip
-bl! Pressure - Low and T°urbine Control Valve Fast c:osure Trio Oi: ?ressure-Law Functions are nqt bypa;sed when THERMAL
?OWER is~ 35.4% RT?.
. hi accordance* with the Surveillance frequency Control .
Program GRAND GULF 3*. 3-5 Amendment Na. ~ 1 ~* Page 19 of F3
* '1 I I I -' * * ,',
II I* : --.: : ~ ' *. *I o
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RPS Instrumentation
. ,; ..... 3. 3 .1. 1
-. - . ; * *,. * . SURVEILLANCE REQUIREMENTS {continued}
SURVEILLANCE FREQUENCY.
- i. . . . : ... *. ,"1.: 3.3.1.1.15 ----~-------------NOTES---------------~--
-. . 1. Neutron detectors are excluded.
2 * . For Fwlctions l, 4, and 5 in
- Table 3. 3 .1.1-1,* the channel sensors-
- may be excluded.
_;--\i (i ,
*..... * ..... . -~
.Jf!ll;:tr~~i~!:z~~~;Pl~ .
~_________ ,..._ .. ____________ *--*-**-*-- ....... ----
.: . ~ :. :. . . *. Verify the RPS RESPONSE TIME is within
* '**: I I
.1 liml.ts ~-
SR 3. 3. 1. 1.16 Deleted
, .. .,
- I S_R 3.3.1.1.17 Perform APRM recirculation flow transmitter calibration.
- SR 3. 3 .1.1.18 Deleted
'II,** ~-*>,.: <*)_: *. _:*.SR ;3 .J ..Ll.19
- Perform CHANNEL CHECK;
* * * *
- I**
- In accordance with the Surveillance
; I*:*
- I *
** frequency Control Rrogrc1m
***,.'.,1'.
- j,
.3.3-Sa Amendment No . -l-8-Eh~
I* I I Page 20 of 173
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*R'PSi *insttµni.Eft):'i;:\:!\t:Jotl
- 3.'3..:1 *. 1
----------------- *NOTE: ---------------- .. ,,
1 . Fqr. F~fictH:m 2,. a, nqt re.quir:e*(f t9 b~ pe.rf g,pr~ed: wtten el'.'l'tcer;fn~: M()?E' 2, . tr*orn *.
. ~PQE *1 ofr~Jl 12 hq'u.t~* c;:ai.;t:,ei,". ,~iit'e.r.:id1g MOPE 2.
2 . }pr:. FiJn:cti9ns . 2\ a, 2 ~.b:, ;and :2.,.; c, ihe
..,Al?:RM/QPB;M Cl1cp)l)els ~nd the'* 2~0tl't:-tlf~4 va:t.et *chan:f1els ate in~ii;id,ed ,in the CH:ANNEL FONt+/-tt>NAL TEST.
3
* ' * ;~iid;:;,~t!l)i;f/.i~ltt~. i~~
,Vo:t;et bh~rt.ri~ls., plli,s the Jl9w i~p*t t-'Qfi4
*fi.rnctiion-.. .exctudin9: fr1e How .
. 't:cl".allSitlit'tEftS I
- ar~ ,ifl'clfa<:Jed I!l the CHANNEL . . lfbNCtl9NJ\:G 'f~st~
SR Sfl 3.3.).1.4~ In accordance with the Surveillance Frequency Control Program
- 3. J~5h Page 21 of 173
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RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 4) Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE .ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.l REQUIREMENTS VALUE
- 1. intermediate Range Monitors.
- a. Neutron Flux - High 2 3 H SR 3. 3. 1.1. l S 122/125 SR 3. 3 .1.1. 3 divisions of SR 3. 3. l. 1.12 full'scale SR 3. 3. l.1.13 5 Ca) 3 I SR 3. 3 . 1.1. 1 SR 3
- 3 .1.1. 4 SR 3.3.l.l.12 S 122/125 _,,
SR 3. 3 .1. 1.13 divisions of full scale
- b. Inop 2 3 H SR 3. 3. l .1. 3 NA SR 3.3.1.1.13
. 5 Cal 3
- I SR 3. 3 . 1. 1. 4 NA SR 3. 3 .1.1.13
- 2. Average Power Range Monitors a *. Neutron Flux~ High, 2. H SR 3.3.1.1.7 S 20% RTP Set down SR 3.3.1.1.lOk!He-)
- 2. Average Power Range 3(~
SR 3.3.1.1.19 ~ ~(C) (d) SR 3.3.1.1.20 ' ~ Monitors (continued)
- b. Fixed Neutron l 3 (e} . G SR 3 . 3. l. 1. 2 S 119. 31 RTP Flux - High SR 3
- 3
- 1. l. 7 3(f1 SR 3.3.1.1.10~
SR 3
- 3
- 1. 1. 19 SR 3.3.1.1.20 (c) (d)
- c. Inop 1,2 H SR 3 . 3
- 1.1 . 2 0
- d. Flow Biased Simulated 1 3( ) G SR 3 . 3 . 1. 1. 2 Thermal Power - High SR 3 . 3 . 1. 1. 7 SR 3,3.1.11 . 1 0 ~
SR 3
- 3
- l. 1. 1 7 SR 3.3.1.1.13 SR 3.3.1.1.19 SR 3.3.1.1.15 SR 3 . 3
- 1. 1 , 2 0
- e. 2-0ut-Of-4 Voter 1,2 2 H SR 3 .. 3.1.1.19 SR 3: 3. l. l. 20 SR 3.3.1.1.21 NA~
1 SR 3 . 3 . 1 . 1 . 2 2 ~(d) C) g
- f. OPRM Upscale ~ 16.8% 3(~ J SR 3.3.l.1.7 RTP SR 3.3.1.1.10 SR 3. 3 .1.1.19 {-£'} .
SR 3
- 3
- 1. 1. 2 0 (continued)
(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. (b) Each channel provides inputs to both trip systems. (c) If the as-found channel setpoint is outside its pre-defined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. (d) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Nominal Trip Setpoint {NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the NTSP are acceptable provided the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The NTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Technical Requirements Manual. GRAND GULF ].3-6 Amendment No. 4-6-9-, -3:-8-8, *9-+/-,* ~ - - - - - - . Format: Move Functions 2.c, 2.d, 2.e, and 2.f to next page. Page 22 of 173
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RP~ I~~t::t@l~.ttt?,tt¢ti 3\3.~).-J
~"r;,sl:o:a:i~t~:~11,~~i;;s!~:grnM:tn:~t,,rtoi,.
Format: Added Table 3.3.1.1-1 to accommodate Functions 2.c, 2.d, 2.e, and 2;;! moved to this page. re,_ ~f Wil=i aa,y ere~t*1=e1 ~tea **i'iHt=teia\Ja :£em a Ceie .'&e11 t:ieafaT~lag: *.eRe *et me>ee L.:..J ~ *fl:le1 aefse#tbli~es .
- H,,): Two"'."Ldot,<Opera't,forii Q.6.4W,. '.f* '6h8% 'RTP. arid ~. l13'Ri RTP
~,,- ~:iii9l$~L9.op .IJpex?tiqn; Q.$'.8.W *+ 3.7:~4**~. RT?
,___, ,1t.-r Ea¢11 c.hahnfi :t,?%9v-{tifs, ippff£s :~.o ~~\h ,tr:tp: sy~it.emfi
~ r ;Jf 'the a:shfoµncr chann~T is*eitpc,int ,,is outside iits; p:r;ijidef1he_a. tfs":".f.oµnd. ~, *
- l;!;i:1;~t~:g.t.~:r1f;~-!i;~lng::}~::a~:!~~~:r:it~_:** i t.:*¢::_;!~.!1,:t*r_t!Y~:::*tc~r 1
,.*i$.**
!~!::. !Z:fs~~: :~~l~*~*i~i::,:1.a:::tth~.i~-~-$~!!~n:i *t:i:~8:tE?t:i~!11:T*;trt*:a:!~\:*~*:;bhin .
9 i=fi!i1ih:):!;i~!i,::;i;::;i.Z:::,rm;:::!:~::~f :;r~ii;::;:t;:r~!!!!:::t t_h1:' }ur,.yetf~,~IlC,13, prgc:1:ciu5~.s.. to q9_rifJr1[1 .. fh,~n11.~:t
-l:~!~r:::c::;.~1!*~:: :t~f!x:*:~tfJn:r:6:~:~*~fttl§~r}th?'.: **~*~*6l~:ft!tf~:q~;2:te~J~.t*s irnB1*~IIl~Jltt;~ :in Mc;µµ:c11. . . ~--
fhe s~H:pdfrrt
-iJ,ehi-f1eci- in /qrth~ Jhe ::dPR~
.c6LR,: . ' ..
- Confirmation
. . lJp,scate'. . . .. . . . . , . .. . {::GDA)
. .. . . --.. - -l)~nsi.ty-,:,A'.lgor}t'hm .. _, .i_!s.*--i---,
~~~@ Jl~.,();;:i':jsit!!;~J;~ i[:~!~t~~;!:~f!,.if9;* !~i:11t,t;~!t~~; ies.et t)ie
.{EBn9t:i().Jf '?+.*9*.L~~tPP.t_.nt:s.. :J:.9 *th~ 1".alµe9 ciefi~~ct:py th.1= C,~Lll. t;q Jwplem~pt ltiie? Ati tblllated: E3SP .$~x:am ~eg}qrj ;iii:. aq_¢ditj~,hc~ with AdtfOt} J *6t .thJs sp~cifiC~t+/-btit -
GRAND GOLF
, Page 23 of 173
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RPS Instrumentation 3.3.1.1 T3ble J,3,l,1-: (prige 3 of 4) ;',~'./
. -C .*
Reactor Pcotectior. Syste~ Instruro~r.tation Al?PLICABU: C-ONDIT!ONS ALLOWABLE MC:JES OR REQUIRE:} REFERENCED V1\LUE OTHE.:R CHANNt::LS FROM SPEClFIED PER TRIP RElJUIRED SURl.'EILL1\NCE FIJ::-ICTION CON.)ITIONS SYSTEJ,,J ACTION [). l REQUIREMENTS
- 3. Reactor Vessel ::;tea!Q t.'ome 1,2 ~. H SR 3.3.I.l.l S U79. 7 psig
!?reSStH!.! {igh
.SR 3.3.l.l.Hi sn 3.3.:.1.:1
.SR 3.3.1.:..12 SR 3.3.~.l.:J SR 3.J.1.1.:5,
- 4. Reactor Vess~l W~ter l .2 2 H SR 3.J.:.:.: ~ 10.@ inches Level - tow, Lc,*el 3 SR 3,J.!,l.S SR 3 . .3.:.1.9 SR 3.3.1.:.12 SR .J.3.l.l.13 SR .J.3,J.J,:5
~. Reactor Vessel Water F SR 3.3.1.:.:::. S 54.1 inchos Level - High, level a SR .J.3.1,I.B SR .3.3.1.l.9 SR 3.3.1,1.:2 SR 3.J.L:.:3 SR 3. 3. l. l. 15
- 6. Main Steam Isolation l G SR 3.3.1.:.a ~ 7% closed Valve - Clo:'H.rc SR 3,3.l.l.i.2 SR 3,.3.:.l.13 SR 3.3.~.::..1~
- 7. Drywcll Pressure High 2 H SR 3.J.l.I.'i. ~ :.4.3 psig SR 3,J,:.i.s SR 3.J.l.1.9 SR 3.3,1.1.)2 SR 3.3.1.:i..lJ
@, Ser~~ Discharqc Vulc~e Water Level --Hig}1
- a. _Tcansmitter/:'rip Unit 1,2 2 H 3R 3.3.J.l.1 ~ 63% .;)f tull SR 3. 3.1..:., ii sc:1le a: *Scram Discharge vo1L1me'. SR
!El 3 * .1.i.. .1. 9 3.3.1.:,1]
Water Level - High (continued) SR 3.3.l.l.i) s}a>', -*. 2 SR 3.3.:.~.l ! 6H of foll SR 3:.3.1.1.8 SC31le SR ],3.1.:.9 SR 3 . .3.l.L:z SR 3.3.:..:.:3 SR _1.J.:.LS -s. 6S i r,cht-s S:t ].3.l.l.12 SR ] . .3.:.:. :i.J I SR .3. 3.: .1. 8 ~ 65 inches SR 3.3.i,:,:2 SR 3.3.1.:..:.3 (c::mtinued) GRAND GUL~ 3.3-7 hrnendment No.~. m Page 24 of 173
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RPS Instrumentation 3.3~1.l Format: Moved Functions 8.b to this page. Table 3. 3, !.. 1- l tpage 'l of 'l) Reactor Protection System lnsLru~er.tatian *~* . APPLICABLE CONDITIONS MODES OR HEQUIRED RE'PERENCED OTHER CJiANNELS FROM Sr'E~H*um PER TK!P R~QOIR~C' Sl'.R\IE.!:LLANC't-; ALJ..OWABU: f'UNCTION CONDITIONS SYS'l'EH ,;1,.CTLON D.l REQUIREMEtr::s VALUE
~
"'1***:**.*
Tur;:;,ir;e Stop \.'"a lve Closure, 3S, ,Jr~ R":'P SR J.3.l.1.1! ~ 31' psig ;::."I'~'\- 7rip Oil ?re~sucQ - low SR ].3.1.l.9 SR 3.3.1.l.l.2 SR 3.3.1.1.13 SR 3.3.Ll.H S'R 3. 3. l. l , 15
- 10. Turhine Co~trol V~lv~ .2: 3!.. 4 \ 'R:'P 2 SR ).).1.1.8 Fast Closure, ~rip Oil SP. J. 3 ,l, l, !)
?res:.urt~ - tnw SP. J. 3. l. !. l:!
SR 3.3.l.l.D SP. 3.).1.l.]II
.SR J.J.l.l.]~
- 11. React~r M~dc Switch - 2 H SR ),3.1.l.ll NA Shutdown Positior. :.lR 3.3.l.l l3 SR 3.3.Ll.ll NA.
SR 3.J.i.l.13 1,2 2 H SR 3.3.l.l.t, NA SR 3.3.l. :..13
~, ia) SR 3. 3 .1. ~, '1 NA SR 3.J.l.:.13
.t.:: ):Si With any mtrnl rod withdmn from a cc;re cell contdining or.e or rncro foel ao,ambllos. 3.3-B Ame.idment Na.~, m Page 25 of 173
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SRM Instrumentation 3.3.l.2 ~ SURVEILLANCE REQUIREMENTS
--~----------------------------------NOTE--------------~~----~---------------- ~efer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MOOE cir other specified conditions,* .
SURVEILLANCE FREQUENCY SR 3.3.L2.1 Perform CHANNEL CHECK. SR 3.3.l.2.2 --------------~---NDTES------------------
- 1. Only required to be met during CORE ALTERATIONS.
- 2. One SRM may be used to satisfy more than one of the following.
Verify an OPERABLE SRM detector is located in:
- a. The fueled region;
- b. The core quadrant where CORE cALTERATIONS are being performed when the associated SRM is included in the*
fueled region; and
- c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.
SR 3 . 3
- 1. 2 . 3 Perform CHANNEL CHECK.
GRANO GULF 3 .3-11 Amendment No * *ia'~; Page 26 of 173
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SRM Instrumentation 3.3.1.2 I SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY
'. * :SR
- 3
- 3 . 1. 2
- 4 ------------------NOTE-------------------
Not required to be met with less than or equal "to four fuel assemblies adjacent to the SRM.and no other fuel assemblies in
'the associated core quadrant.
Verify count rate is: a, ~ 3.0 cps, or
- b. 2 0.7 cps with a signal to noi_se* ,AND ratio ~ 2: 1.
* *: I
'-~ ,!16~i:*¢>' '
. )
SR 3.3.1.2.5 ----------------*-NOTE------------*_-**-* .....*,.. , .. Not required to be performed until_:.* .. , 12 hours after IRMs on Range 2 or )::>~l;Qwi, Perform CHANNEL FUNCTIONAL TEST.
. . SR 3.3.1.2.6 ~ - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - .. :*:.: :, . , .<:*.,:; '.* *'.".....
- 1. Neutr.on detectors are excludeq, ..
- 2. Not required to be performed utr~:(;;t 12>
hours after IRMs on Range 2 or>l:>t:al:¢\'h
- - - -- - --- - - - --- - - - - - ---- - ---- - - -- _* .*- ~'.. *' :.'.': . .:* *.:.:--'
i ( Perform CHANNEL CALIBRATION. GRAND GULF 3.3-12 Amendment Na*. 4-r0,;~. ',J~~?J Page 27 of 173
Page 28 of 173
- ibeleted 3',ftJi'f)l
\
Page 29 of 173
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Control Rod.Block Instrumentation 3.3 . 2.l SURVEILLANCE REQUIREMENTS
- l. Refer to Table 3.3.2.l-l to determine which SRs apply for each Control Rod Block Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into assoc;ated Conditions and Required Actions may be *delayed for up to 6 hours provided the associated Function maintains control rod block capability.
SURVEILLANCE FREQUENCY SR 3.3.2.l.l *----------------~NOTE------------------- Not required to be performed until l hour after THERMAL POWER is greater than the RWL high power setpoint (HPSP). Perform CHANNEL FUNCTIONAL TEST. SR 3 . 3 . 2.1.2 ------------------NOTE---------------* -- " . Not required to be performed until l hour :
- after THERMAL POWER is> 35% RTP and less than or equal*to the RWL HPSP.
Perform CHANNEL FUNCTIONAL TEST. SR 3.3.2.1.3 --------*-~**--*--NOTE------------------- Not required to be performed until l hou~ after any control rod is withdrawn at s 10% RTP in MODE 2. Perform CHANNEL FUNCTIONAL TEST. , GRAND GULF 3.3-]5 Amendment No. :-~-~:;i Page 30 of 173
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Control Rod Block lnstrumentation 3.J.2.r SURVElL~ANCE REQUIREMENTS {continued) SURVEILLANCE FREQUE:NCY SR 3.3.2.1.4 ------------------NOTE---------.--------- Not required to be performed until 1 hour after THERMAL POWER is .S 10% RTP in
~ODE 1.
Perform CHANNEL FUNCTIONAL TEST. SR 3, 3. 2. 1. 5 Calibrate the low power setpoint trip units. ,The Allowable Value shall be
~ 10% RTP and~ 35% RTP.-
SR 3
- 3
- 2
- 1. 6 Verify the RWL high power Function is not bypassed when THERMAL POWER is*> 70% RTP.
SR 3, 3. 2. 1. 7 Perform CHANNEL CALIBRATION. SR 3 . 3 . 2 . 1. 8 ~-----------------NOTE------------------- Not required to be pe~formed until 1 hour after reactor mode switch is in the shutdown position. Perform CHANNEL FUNCTIONAL TEST. GRAND GULF 3.3-16 Page 31 of 173
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PAM Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS
- - - * - - - - . - - - - - - - - - - - - - - - - - - - - - - * * .. - NOTE - - - - .. - - - - - - - - - - - - - - - - - - - - - ' - - - - - - - - * - - . *. ::. :These. .SRs. .:apply to each Fun~tion in Table 3.3.3.1-1.
. ', . \ -- . --- --- -- - -
- - . - - - - - ' - - ... - - - - - - -- - - - - - - - ....... *.... - ----------- ---~- - -.... - - - -- -- .
SURVEILLANCE FREQUENCY
; .. SR 3.3.3.1.1 Perform CHANNEL CHECK.
SR 3.3.3.1.2 Deleted SR 3.3.3.1.3 ------------------NOTE------------------- Neutron detectors are excluded . Perform CHANNEL CALIBRATION. lhaccordance with
- the Surveillance
. Frequency Control Prqgram
. GRAND GULF. 3.3-21 Amendment No . 1"66,
- 1:.9?;
- Page 32 of 173
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Remote Shutdown S1stem 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.Z Remote Shutdown System LCD 3.3.3.2 The Remote 'Shutdown System Functions shai l be OPERABLE. APPLICABILITY: MODES 1 and 2. ACTIONS ~;~;~;~~ *c~~~; ~; ~~ -~~~~;-; ~. ;~ j ~~;~ -f~~T!;~~ *;~~~~j~~:. --- -.. -.... --., -... -.-~, CONOll ION REQUIRED ACTION COMPLETION TIME A. One or more required A .1 Restore required 30 days Functions inoperable. Function to OPERABLE status. B. Required Action and B.l Be in MODE 3. 12 hours associated Completion Time not met. lri accordance With the- -
-: tiurveillance Frequency Control _.*.- - - - .
*. Program SURVEILLANCE REQUIREMENTS-SURVEILLANCE SR 3.3.3.2.l Perform CHANNEL CHECK for ea;ch :requ:tT,~cf instrumentation channel that tt hdffu~11J' energ1 zed.
(continued} GRAND GULF 3.3-23 Amendment No. +.W;,,,::J7§"::, , Page 33 of 173
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Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS {continued) S:JRVEILLl\NCE FREQJENCY. SR 3.3.3.2.2 Verify each required concrol circuit and cransfer switch is capable of perfor~ing the intended fur.ctioTI5, SR 3. 3. 3. 2 .. 3 Perforrri CHANNl::L CALIBRATION for each requi~cd instrumentation channel. In accordancewith
- the Surveillance
** i=:-requency Control Program GRAND GULF J.3-2_4 Amendment No. ~*JQ7 1 Page 34 of 173
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EOC-RPT Instrumentation
- 3. 3. 4 .1 SURVEILLANCE REQUIREMENTS
NOTE-------------------------------------
When a channel is placed in an inoperable status solely for performance o1 required Surveilla~ces, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function mai~taini EOC-RPT trip capability. SURVEILLANCE FREQUENCY
/
SR 3. 3. 4. 1.1 Perform CHANNSL FUNCTIONAL TEST. SR 3.3.4.1.2 Calibrate the trip units. SR . 3. 3. 4. 1. 3 Perform CHANNEL CALIBRATION. The Allowable Values shall be:
- a. TSV Clcis~re, Trip Oil Pressure - Low:
~ 37. psig.
- b. TCV Fast Closure, Tcip Oil Pressure - Low: 2'. 4 2 psig.
SR
- 3. 3 . 4 . 1 . 4 Perform LOGIC SYSTEM rUNCTIONAL TEST, incl~ding breaker actuation.
SR 3 .. 3. 4. 1. 5 Verify TSV Closure, Trip Oil Pressure - Low and '!.'CV Fast C.losure, ~~*rip Oil Pressure...: Low* Functions are not bypassed when THERMAL POWER is 2: 35. 4.% R':'P. G;RANq*GULF 3,3-27 Amendment No. 12;e;: ,f~},,. Page 35 of 173
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. - *EOC-RPT InstruIT':entation
. 3. 3. 4 .1 SURVSI LLA~JCE ?.EQTJ:!:°REME~TS (continued)
SURVEILLANCE Fi<EQUE~CY SR 3. 3. 4 .1. 6 --------------- ~-NOTE------------------- Breaker interruption time may be assumed from the reost recent performance of SR 3. 3. 4. 1. 7. Verify the EOC-RPT SYSTEM R~SPO~SE TIME is within limits. SR 3. 3. 4 .1. i Determine RPT breaker interrupcion time. GRAND GUU' Amendment: ~o. H-G; .i9'.;r:-, Page 36 of 173
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ATWS-RPT Instrumentation 3.3.4.2 .\__) ACTIONS (continued) I I CONDITION REQUIRED ACTION COMPLETION TIME B. One Function w;th 8.1 Restore ATWS-RPT trip 72 hours ATWS-RPT trip capabi1 i ty. capability not
,maintained.
- c. Both Func~ions with C.1 Restore ATWS-RPT trip 1 hour ATWS . . RPT tri'p capability for one capability not Function.
maintained. D. Required Action and D.1 Remove the associated 6 hours associated Completion recirculation pump Time not met. from service.
!IB D.2 Be in MODE 2. 6 hours l
SURVEILLANCE REQUIREMENTS
------*------------------~-----------NOTE-----------------~-------------------
When"a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Condi.tions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability. SURVEILLANCE FREQUENCY
. SR 3 *3 *4*2*1 Perform-CHANNEL CHECK.
GRAND GULF 3.3 ... 30 Page 37 of 173
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ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREM~NTS (continued) SURVE:!:LI..ANCE FREQUENCY SR 3.3.'1.2.2 Perform CHANNE~ FUNCTIONA~ TEST. SR 3.3.4.2.3 Calibra~e the trip u~its. SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable Values shall be:
- a. Reactor Vessel Water ~evel-low ~ow, Level 2: ~ -~3.8 inches; and
*b. React:or Vessel Pressure - High:
S 1139 psig. SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation. In accordance with he Surveillance Frequency Control
. Pr~gram .
GRAND GULF J.3-3 J *Amendment No. 1~~~;J9:7~ Page 38 of 173
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i" : .... ECCS Instrumentation 3.3.5.1 SURVE!LL~CE REQUIREMENTS
'- - * - -. - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
- 1. Re~er to Table 3.3.5.l*l. to determine which SRs apply fo.r each ECCS
. .. . ... * ***Function .
- 2..
- When a channel i~ placed in an inoperable status_ solely for performance of
. requir:ed Surve.illances, . entry into associated Conditions and Required
.* .*. Ac~ions may be delay~d as follows: (a) for up .to 6 hours for Functions 3.c*, 3.f, 3.g, and 3.h; and (b) for up to 6 ;tiours for Functions
-.._ ~ othe~ than 3. c r 3. f, 3. g, and 3. h, provided the associated Function or the redundant Function maintains ECCS initiation capability.
J I.*', I* SURVEILLANCE FREQUENCY SR. . 3 . 3 , 5 . 1 . l Perform CHANNE~ CHECK. I
'\
SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST.
.: ~
SR 3
- 3
- 5
- 1. 3 Calibrate the trip unit.
.. t :-
SR 3
- 3 . 5 . l .4' Perform CHANNEL CALIBRATION.
SR 3 . 3 . s .. 1. s Perform CHANNEL CALIBRATION.
. SR 3.3.5 .l .6 Perform LOGIC SYSTEM FUNCTIONAL TEST .
GRAND GULF 3.3-38 Amendment No. 420-. :a'.Q:t, Page 39 of 173
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' RCIC System Instrumentation 3.3.5.2
-SURVEILLANCE REQUIREMENTS
--------------------~----~--~----*--*NOTES-----------------------------------
. 1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function,
- .
- i* .. W:nen a charu{el is placed in an inoperab,le status solely for performance of required*Surveilla~ces, entry into asso~iated Co~~itions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 2
. anp.. S.; and (b) for up to 6 hours for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.
* .. ---~-*-M----A---~-*--~---------------------~-~--~------~----~-~-~-----~------
SURVEILLAN~E FREQUENCY SR 3 . 3. s*.2.. 1 Perform CHANNEL CHECK. SR 3, 3 .5. 2 2 Perfo*rm CHANNEL FUNCTIONAL TEST.
. ! ~ .*
s'.R 3 :. 3 , 5 , 2/. 3 Calibrate the trip units . SR 3.3.S.2.4 Perform CHANNEL CALIBRATION. SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL' TEST. GRAND 'GULF* 3.3-46 Amendment No. -tz-0; >~*,qf,
- I.
Page 40 of 173
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Primary Canta i nment and Drywe 1..1 .. I so I at ion Instrumentation 3.3.6.1 SU~VEILLANCE REQUIREMENTS
*. :-*.------.--*--------------------------NOTES --------------.*-*-.------------*'*----
.. * * *.. - ... *r. R*efer to *Table 3. 3. 6 41-1 to determine which SRs apply for each Function.
-2.
- When a channel is placed in an inoperable status solely for performan~e of
* . :
- required S_urveillances, -entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function mai~tains isolation capability.
SURVEILLANCE FREQUENCY
*SR 3.3.6.1 .1 Perform CHANNEL CHECK.
SR
- 3
- 3 . 6
- 1. 2
- Perform CHANNEL FUNCTIONAL TEST.
- SR - -3
- 3 . 6 ._l
- 3 Calibrate the trip unit.
SR 3 . 3
- 6
- 1. 4 Perform CHANNEL CALIBRATION . .*~*- da=:~~
.*. *,'.~ .
.!E;.;;.....:........,_......,..........;.;;;m
*SR 3 *3 . 6 .1 . 5 Perform CHANNEL CALIBRATION.
SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. Perform CHANNEL CALIBRATION. Perform LOGIC SYSTEM FUNCTIONAL TEST. GRAND GULF 3.3-53 Page 41 of 173
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.** 'Primary Containment and Orywell Isolation lnstrumentation
- ~~. . . . . . ~* Format: Moved SRs' 3.3.6.1. 7 and 3.3.6, 1.8 to thi~ page. 336 1 c,SURY,I;.:I:S:..ANCE I~EQIJIRE~ENTS ( continued}
SURV~I:'.:c,LANCE FREQUENCY SR J. 3. 6. 1. 9 ----- -------------NOT~----------------- Channel sensors may be excluded .
., , ..._.,, .. ( ..... -* .... *., ... ***:' .. *.,: .. .. * . . .
......-------------------~
~ '
- sii.sis\ ** *
- SR J. 3. 6. 1. 10 -------------------NOTE------------------ ' .'lJ
./~.. * .*
- Only required to be performed when function 5.b is not OPERABLE as allo~ed
*-1?~. NJq;t~';: (h ) of Tab 1 e 3 . 3 . 6 . 1-1 .
~e-':?--------------------.
}fo.otnot~loiioit--*.................***--****-*****-<.... ------------
pressure vessel flange. 1n* accordance with
- tbe Surveillance Frequency Control
*Br.<?gr.~rn. . "
GRANO GULF 3.3*53a Amendment No. ffi~\ Page 42 of 173
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Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME
- c. (continued) C.l.2 Declare associated l hour secondary containment isolation valve(s) inoperable.
AND C.2.1 Place the associated l hour standby gas treatment (SGT) subsystem in operation. OR C.. 2.2 Declare associated 1 hour SGT subsystem inoperable * .SURVEILLANCE REQUIREMENTS
,. ... - ... ~ .......... - - .. - _,_ ---- ..... ~,_ - .. ._......... --~ ........ **** ... NOTES** ........ * ....... ***** .... *~* ... ,_ .... ** ..... - * . ,. ..... _,. **
- 1. Refer to Table 3.3.6'.2-l to determine which SRs apply for each Secondary.
Containment Isolation Function.
- 2. When a channel is placed .in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required .
Actions may be delayed for up to 6 hours. provided the associated Function maintains secondary containment isolation cJapability.
-----*-------------------~**a-----*~*-*-~---*----*-----------*----*-*-----*---
~ SURVEILLANCE FREQUENCY SR 3.3.6.2.l Perform CHANNEL CHECK.
GRAND GULF 3.3-60 Amendment No. ;~l2]~~:, Page 43 of 173
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Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE* REQUIREMENTS (continued} SURVEILLANCE FREQQENCY
=SR 3 . 3 ..6 . 2 .. 2 Perform CHANNEL FUNCTIONAL TEST.
I ~ I
'SR 3.3.6 .2 .3 Calibrate the trip unit.
.... *.*. . . .. SR 3.3.6.2,4 Perform CHANNEL CALIBRATION.
- I
- 1, '":,, * ~ "
SR J.J.6.2.5 Perform OHANNEL CALIBRATION.
$R 3.3.6.2.6 Perform LOGIC SYSTEM FUNCTIONAL TEST.
'SR 3*. 3. 6. 2. 7 . - - . - - ~ - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - . - -
Radiation detectors may be'excluded .
*~ *.
. GRAND GULF 3.3-61 Page 44 of 173
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RHR Containment Spray System Instrumentation
. 3.3.6.3 SURVE!LLANCE*REQU!REMENTS
~----------------NOTES--.--------------~-------------------
- 1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each RHR Containment Spray System Function.
- 2. Whe~ a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Con~itions and Required Actions may be delayed for up to E hours, provided the associated Function maintains RHR containment spray initiation capability.
1-~---------------------~----------------------~---------------
SURVEILLANCE FREQUENCY SR 3.3.6.3.l Perform CHANNEL CHECK, SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.3.3 Calibrate the trip*unit. SR 3.3.6.3.4 Perform CHANNEL CALIBRAT!ON. SR 3.3.6.3.5 Perform CHANNEL CALIBRATlON. SR 3.3.6.3.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. GRAND GULF 3.3-65 Amendment No. 120~:J,2.7: Page 45 of 173
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1.~.P. MU System Instrum. entatio.. n.
. * . . 3.3.6-4 SURVEILLANCE REQUIRE~ENTS
~---NOrEs------------------------------------
- 1. Refer to Table 3.3.6.4-1 to deterrnine which SRs apply for each SPMU F'unction.
- 2. When a chan~el is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains SPMU initi 9 tion capability.
SURVEILLANCE FREQUENCY SR 3.3.6.4.1 Perform CHANNEL CHECK. SR 3.3.6.4.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.4.3 Calibrate the trip unit. SR 3.3.6.4,4 Perform CHANNEL CALIBRATION. SR 3.3.6.4.5 Perform CHANNEL CALIBRA'l'ION. SR 3.3.6.4.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. GRAND GULF 3.3-69 Amendment No.~,~; Page 46 of 173
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Relief and LLS Instrumentation JJ.6 ..5 SURVEILLANCE REQUIREMENTS
NOTE-- -----------------------------------
When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the asaociated Function maintains LLS or relief initiation capability, as applicable. SURVEILLANCE FREQUENCY SR 3.3.6.S.1 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.S.2 Calibrate the trip unit. SR 3.3.6.5.3 Perform CHANNEL CALIBRATION. The Allowable Values shall be:
- a. Relief Function Low: 1103 +/- 15 psig Medium; 1113 ;t 15 psig High: 1123 +/- 15 psig
- b. LLS Function Low open: 1033 +/- 15 psig close: 926 +/- 15 psig Medium open: 1073 +/- 15 psig close: 936 +/- 15 psig High open: 1113 +/- 15 psig close: 946 +/- 15 psig SR 3.3.6.5.4 Perform LOGIC SYSTEM FUNCTIONAL TEST.
GRAND GULF 3.3-72 Amend_ment No. ~ f¥!::.*, Page 47 of 173
*eRFA 5;)'$,tent.*h~st;:-i:lmeat.a~i'CfA
*** ;a:.a:.J;~:11.
Page 48 of 173
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CRFA System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS
~OTE-------------------------------------
When a channel is placed in an inoperabie status solely for performance of required Surveillances, entry into associated Conditions and. Req~ired Actions may be delayed for up to~ hours provided CR isolation capability is maintained.
* ----~----~----------------------------------------~-~-~
SURVEILLA~CE E'REQUE~CY SR 3. 3. 7. 1. 1 Perform LOGIC SYSTEM FUNCTIONAL TEST.
. Next page is. 3.3-77 GRAND GULF Amendment No.'~~** ~r Page 49 of 173
+a ale *3 ~ 3. 7 ~ 1 .1 *
.*Delete a GRMHl CHLF *.
Page 50 of 173
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LOP Instrumentation 3.).8.l SURVEILLANCE REQUIREMENTS
. ------------~-NOTES- -----~---------~-------- -----------
- 1. Refer to Table 3.3.8.1-1 to determine which SRs. apply for eac~ LOP Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains DG initiation capability.
SORVEILLANCE tREQt;ENCY SR 3 . 3 . 8*. 1 . 1 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. SR 3.3.8.1.3 ~erform.CHANNEL CAL:3RAT!ON. SR 3. 3. 8. I. 4 Perform LOGIC SYSTEM rUNCTIONAL TEST. In accordancewith the Surveillance Frequency Control Program GRAND GULF }.Jv78 Amendment No. -l,!,Q,4¥/, Page 51 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RPS Electric Power Monitoring 3.3.8.2 t I ACTIONS (continued)
\_)
CONDITION REQUIRED ACTION COHPLET ION TIME D. Required Action and D.l Initiate action to Immediately associated Completfon fully insert all Time of Condition A or insertable control B not met in MODE 4 rods in core cells or 5 with any control containing one or rod withdrawn from a more fuel assemblies. core. cell containing one or more f ue1 assemblies. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.l ------------------NOTE------------------- \j Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for~ 24 hours. Perform CHANNEL FUNCTIONAL TEST.
.:c§o'fifin'1~c1>
GRAND GULF 3.3-81 Amendment *NQ'.~:**~liQ:J\ Page 52 of 173
. :- ... *:. :<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RPS Electric Power Monitori~g
.: "'\
3*.3.a:2 *
** *:*: I ; I
- . I * ',.I,
*sURVEILLAN~E REQUIREMENTS* (continued)
SURVEILLANCE FREQUENCY SR 3 . 3 . 8 __- 2 . 2 Perform CHANNEL CALIBRATION. The Allowable Values shall be:
- I* ~ * ,' **
- a. Overvoltage
.. ; *, Bus A 5 132.9 V Bus Bi 133.0 V
- b. un4ervoltage Bus A~ 115.0 V
. .. .-~ Bus B ~ 115.9 V
- c. Underfrequency (with time delay set to s 4 seconds)
Bus A~ 57 Hz Bus B ~ 57 Hz
*SR 3
- 3
- B. 2 *3 Perform a system functional test.
In accordance with *
.* the Surveillance Frequency Control Program_
GRANO GULF 3.3-82 Amendment No . 'Tie. J.9.7,, Page 53 of *173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Recirculation Loops Operating 3.4.1 SURVEILLANCE REQUIREMENTS I u SURVEILLANCE FREQUENCY SR 3.4.1.1 -*------------*----NOTE.-*----*------*----- Not required to be performed unti1 24 hours after both recirculation loops are in operation. Verify recirculation loop jet pump flow mismatch-with both recirculation 1oops in operation is:
- a. s 10% of rated core flow when operating at< 70% of rated core flow; and
- b. ~ 5% of rated core flow when operating at~ 70% of rat~d core flow.
' J.;,,
..:"_if:_*
In accordance with
. he Surveillance
- Frequency Control _
*. Prqgram
.J.AL, GRAND GULF 3 .4-4 Amendment No. '1-rG, -.**-~
k~~
**,IAt.:t *1* * * * - ~
-~:r~*,:,~*;
[Next page IS 3.4-6 .* 173
u
. ..Rage s.,~*5
*> ****.as o.een temovSd**** . *
** . **. pet uaense ..
. Am: *. **.*.dment No t41
~ i,~.:t*>e** ,A -_-\1--
*-.**Q* . _:_:*U
- c1*-*
-_ *:* * **n.*-.*:_ .u**_:_*.,a_*_*--*----_._._:_. ry*_*_-._--.--_--: *_-_.*
;J
- n,o.*;:n.
**2-*
*.:.V-.:* . . ll*
0 Page 55 of 173
I~ *.
<Admin.istrative: Reformatted page in accordance with ISTS Writer's Guide>
*FCVs 3.4.2
. 3.4 REACTOR COOLANT SYSTEM (RCS)
- 3. 4. 2 .* Flow Contra I Va Ives (FCVs)
*,: f I
- LCO 3*. 4. 2* A recirculation l_oop FCV shal I be OPERABLE in each operating recirculation loop.
- o ~* I ': ' ::* *
- _.. . * .,.. *. APPLI CAB l LI TY: MODES 1 and 2.
._:* :*::*_:.... ;: .. 'ACTtONS
----. *------------.-~----------------NOTE------- -----------------------------
~~parate C~ndition entry is al lowed for each FCV.
CONDIT I.ON REQUIRED ACTION COMPLETION TIME A. One or two required A. 1 Lock up the FCV .. 4 hours
. *FCVs inoperable .
. *.: I ~I I lo I .. ..,
,,i.
*....*_ c B.. Required Action and 8.1 Be in MODE 3. 12 hours
*. -* ,,
- assoc; i ated Comp I et.i cin
* ,* ', L ** ~ * ...
Time not met.
- SURVEILLANCE REQU I REMENTS SURVEILLANCE FREQUENCY.
SR 3.4.2.1 Ver i fy each FCV fa i I s **as i s" on J oss of *.*r4 :fflORt:t,s.,;.-.,...--------* t' hydrau I ic pressure at the hydrau I ic unit: GRAND GULF 3.4-6 Amendment No . -l26, i;;>7'* Page 56 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
FCVs 3.4.2
-SURVEILLANCE REQU I REMENTS (continued)
SURVEILLANCE FREQUENCY
. ; *.. SR 3. 4. 2.. 2 . .Ver i ry average rate of each FCV movement '
is:
~. *.... :' .. - ,* a. ~ 11% of stroke per second for opening; and
- - *.. ~- .
- .-.\:*:.**.::
- b. ~ 11% of stroke per second for closing.
In accordancewith> *
- he Surveillance Frequency Control F>rogrc.:1m .
~
I
. \. .
~- . -. : .
=.. : : : * ** *
~
*, * '.'*~:
- I ' *
"GRAND GULF 3.4-7 Amendment No . T2e. * ;l9}7
- Page 57 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Jet PuMpS 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.l ----------~------NOTES-------------------
- 1. Not required to be perforMed u~til 4 hours after associated recirculation loop is in operation.
- 2. Not required to be perfor~ed until 24 hours after> 21.6i RTP.
Verify at least two of lhe following criteria (a, b, and c) are satisfied ftifk( each operating recirculation loop:
- a. Recirculation loop dr i Ve fl OW verso:s flow control valve position differtbi
~ 10% froM established patterns. *** * **
- b. Recirculation loop drive flow versLl~-
total core flow differs by $ 10% frpnf established patterns.
- c. Each jet pump diffuser to lower pl~ri:ufo
- differential pressure differs by sao, from established patterns, or each~jjt pump flo~ ~iffers by~ 10% from established patterns.
***:i ... **.* .-
In accordance.with the Surveillance Frequency Control_ prqgram.. . . GRAND GULF 3.4-g Amendment No. 2-e, * ~ Page 58 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
S/RVs
...
- 3.4.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3 .4 .. 4 .. 2 -------------------NOTE-----------------.--
. ..* : .... *, Va.lve actuation may be excluded .
;.** .. **: Verify each required relief function S/RV actuates on an actual or simulated automatic initiation signal ..
. .. SR 3-.4 .4 .3 - - - - - - - - - - - - - - - - - - -NOTE- - - - - - - - - - - - - - - - - - -.~
N9t*required to be performed until 12 hours after re~ctpr steam pressure and flow are adequate to perform the test. Verify* each required S/RV relief-mode . In accordance
. ,, . actuator strokes when manually actuated. with the
*.In~~:l:"\::fqJ.?:
INSERVICE TESTING PROGRAM.
- ,~!f1i~iPI
*. ea:ch. -t~lve
* ~<>i~noJ.a.. _*
t, -~ *
. /.
GRAND GULF 3.4-11 Amendment No. Be.,,~* Page 59 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RCS Operational LEAKAGE 3.4.5 ACTIONS (continued) CONDITION REQUIRED ACTION . COMPLETION TIME C. Required Action and C.l Be in MODE 3. 12 hours associated Completion Time of Condition A AND or B not met. C.. 2 Be in MODE 4. 36 hours Pressure boundary LEAKAGE exists. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3 . 4.5.1 Verify RCS unidentified LEAKAGE, total ~:2:hettJ.s<: LEAKAGE, and unidentified LEAKAGE increas~ are within limits.
- In accordance With ...
- the Surveillance
.~**
. Frequency Control Program GRAND GULF 3.4-13 Amendment No *..,12&\
Page 60 of 173
\j}fJ(i;:;:.:. .;. . :.' . .<Administrative: Reformatted page in acco,rda.nce
. with ISTS Writer's Guide>
- RCS Leakage Detect'ion- Instrumentation 1
. ... ~*. . *:. . : 3 .. 4. 7 .
},:," ::*** :. ... i!\l!il~J:!~:;if ~r?t~*/:::::::~ON E * * *Required drywell
. REQUIRED ACTION COMPLETION TIME'
;~;!~~;r~::sys~e~
**, * **i **"***-. *
- E.l Restore required 30 days drywell atmospheric rn;_:i,(_}?t: :i(;. '. monitoring system to OPERABLE status ..
t ~: - . ~* ..*. *. t::*:\ :/,_;:<\* '.:,-. *r. . * . AND
- OR 30 days*
(i. :*\)i~**:*.\*< ~'k: *:r\*; *... : . :
'. i,. ~~:!!a:!r *::te f~~~
monftoring system 1 E.2 Restore d:t;ywell air cooler*condensate flow rate monitoring system
.. . . . * '"t ... 1~ .. *
- i:nop_erable: to 'OPERABLE status. .
.* . . .. ~. : , .
- t}_\\<
- (;:,. \. -,.,*/ ~-* *-. *~'=:qu.i 7ed .A;t+/-o~ ~n~ Be in Meee 3. 12 hours
~
- '*,::*.:*'..3**, **.** **.::* ~.'-:. ;.. ~ : .. ,
- assocJ:ated Completion
))Iti(f: *: :;'.'):.:.:**:*-;: ;:; o~ ,.c~;d!t!~: _A,.
AND F.2 Be in Meae 4. 36
- hour~ :*
- J ,1 .**:
- . * .*,:* *:. . *'G~* ~11 ,re*quired .leakage G.1 Enter LCO 3.0.3 Immediately
,\i \i:'.: .* :... *.. .t:~;~;!:e~ystems
- .-.\/\.
- .~~*,:::..*_: *.*.=. =========================== ========='===========
\' ?_(\t\: *.:'. : :. SURVEILLANCE REQUIREMENTS
., SURVEILLANCE FREQUENCY
=SR .'3. 4. 7*.1 Perfo~m'CHANNEL CHECK of required drywell atmosph~ric monitoring system. r I (continued) -1 -
- Perfoim*CffANNEL F~CTIONAL TEST of 31 eays+<.......*-*---*-*--
.required leakage detection instrumentation . . ;*.*.*~*:; ~?=/. ~ : .:.
(.:i{)Y< SR 3.4.7°.3 Perform CHANNEL CALIBRATION of required leaJfage detection instrumentation. 24 meaths ~ .* *>:**\)/i:.: ::._:,**-===*.-~.======;::==:==~============= =;::=::=::=::=::=::=::::;== In accordance with the
*) .*i=o~mat: ...Move S.Rs 3.4.'1.2. and 3.4.7.3 to new Page 3.4-18a. Surveillance Frequency
- ~ :., .. .
Control Program
*~ .. :
3.4-18 Amendment No.~, ~, P~ge 61 of 17*3
.<:Ad~inistrative: R.eformatted page in a~co,rda.nce with ISTS Writer's Guide>
1 RCS Leakage Detect*ion* Instrumentation
*}. ' ... ,* . *:. : 3.4. 7 ..~ * .
- I
~
REQUIRED ACTION COMPLETION TIME' E.l Restore required 30 days .-.. ~, ** ** * ~ *** .. ** ** ** .... *
- atmospheric
- drywell atmospheric
- }}{(,
- :.:::;:::::*: . ::;:~;~!~~'. syst~m monitoring system to OPERABLE status ..
i)t:t.r::f.-.. (:*: .*, AND. .
- -':/;:* :-..*.:** . *. :.**. Drywe~l ~1r cooler*
OR E.2 Restore d:r;ywell air 30 days*
*:;. *._":_/:.:<': /: ..:; :.::* *:*.: .* condensate* flow *r.ate cooler*condensate flow
.* :*>- *.~*:::.,: *; *... : . : monftoring system rate monitoring .system
'* . . *"; * .. 1. * ***
inop_eraple ~ to *oPERABLE status. .
. :. : ..... ~
tULi\:LiJ~.: . t:t!~:!~~7~!~:1:~tn Be in Meee 3. 12 hour~
~}y;;~f\: :\*: : ;:/.:.:**:* .:~:~; *:c~;~!t!~~ o~ .A,*
AND
~ 36. hours*
.. . ~: .
JO * ~. F.2 Be in MeE:ie 4.
. ~11 ,re*quired .leakage G.l Enter LCO 3.0.3 Immediately
- \*
- :**::::\:. :-,:.: detection systems
; * ){i/,;), -7* .... *inop'erable.
- -'\\::) \ f S~VEILLANCE REQUIREMENTS
., SURVEILLANCE FREQUENCY
~ . . ...**
Perfo~m'CHANNEL CHECK of required drywell ~ ~ / atmosph~~ic monitoring system. I I (continued)t--t 1 -
- Perform*CHANNEL F~CTIONAL TEST of 31 days<*.
.required leakage detection :
instrumentation. Perform CHANNEL CALIBRATION of required 24 meat.as ~ 3.4.7".3 leakage detection inst*rumentation.
¥
*.:){*:i:\*:_;::.:***.=:='.":=.==**==**=~=:===:==============================:::;==
.** =.\.:* . .-. :. *f=o~mat: Move S.Rs 3.4):.2 and 3.4.7.3 to new Page 3.4-18a. In accordance with the
.. *. . Surveillance Frequency
,.* .* Control Program * -.
-~' :_ :-:*./.:: *;=:* *. *: / G ~ GULF 3.4-18 Amendment N o . ~ ' ~
P~ge 61 of 17*3
'.:r{tI:r\ rri:::'..*' *' 1
<Insert Page 3.4-1 Ba>
.RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of In accordance with required leakage detection instrumentation. the Surveillance Frequency Control Program SR 3.4.7.3 Perform CHANNEL CALIBRATION of required In accordance with leakage detection instrumentation. the Surveillance Frequency Control Program GRAND GULF 3.4-18a Amendment No. Page 62 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RCS Specific Activity 3.4.8 u SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.l *-- --- ---*--- -- --... - --NOTE-- . . - ------ -- -- --- - -- Only required to be performed in MODE 1. I Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity is
- S 0.2 pCi/gm.
.. *'*: ... .........* i.i'
. lri accordancewith
- the Surveillance
\ 'prequency Control Program ',".::* GRAND GULF 3 .. 4-20 Amendment No,. :;~;: Page 63 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RHR Shutdown Cooling System - Hot ShuLdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVE ! l.L/\NCr,: FREQTJ8NCY SR 3. ,j. 9 .1 -------------------NOTE-------------------- Nct requi~cd to be mot until 2 hours after
- -ea,.;lo~ s Lear-, dorr1*2' !)!'."essuce is less tha11 the RHR cut ir. pc~~:ssivc pres8~re.
.*.1g In accordance with the Surveillance frequency Control Program.
GRAND GrJI,F 3.4-23 ,,;me r.(imen t No. ~ , . ~ Page 64 of 173 ,
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
R.!-IR Shutdown C:ool i ng System - Cold Shutdown J.4.10 ACTION~ (contin~cd) CONDlTlON REQUlRED ACT lON COMPLETION T!ME I::L No Rr.R shutdown B. l Verify re.:ictor l hour from cooling subsystem in coolant circula~ing discovery of no operation. by an alternate reactor coolant method. circulation J\N:J AND No recirculation pump in operation. Once :r-,er 12 hours ther:eafter B.2 Monitor- reactor coolant t~rnperaturc and pr.essure. STJRV~lLLANCE XEQUlfl.£:;MEN'l'S SlJRVEl!...LANCE FREQUENCY SR 3.4.10.1 Verify one P.HR shut.down cooling s*.Jbsystem . i.2 ijptff-S*'*.....,..............._ _..........,..*. or reclrculation pump .1s operating. SR 3.4.10.2 verify ~HR shutdown cooling subsystem locations susceptible to gas accumulation are sufficien;ly filled with water. GR.~ND GULF 3.4-25. A.rnendment No. ~ ' , ~ Page 65 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
HCS P/'f Limits
- 3. 4 .11 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME
- c. ------.:..NOTE--------- )C .1 Initiate action to Immediately Required Action C.2 restore parameter(st shall be co~pleted if to within the limit.s this Condicion is specified in the entered. PTLR.
AND Requiremen~s of the LCO not met in other C.2 Determine HCS is l?rior to than MODES 1, 2, acceptable for entering MODE 2 and*3. aperat.ion. OI" 3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
\
SR 3. 4. 11. 1 ------------------NOTE------------------- Only req1Jired tn be performerl rlurinlJ RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing. Verify:
- a. ,RQS> p:,:e:ssure: .antj. RCS tempera t.ur:e a re
~ftl')fn th~ .1:hnits speci tied in the PTLR bas.~d; 6n ~he current . ;Effeet:.L~
',.':Fhhi po):e't. Ye~r. {EFPY) I and
- b. RCS heatup and caoldown rates are wiLhin the limits specitied in the PTLR.
(hbnt£9u~~} .. In accordance with the Surveillan*ce Frequency Control Program
- GRAND GULF J. 4-27 Amendment Ne. ~ , ~ , , Je~J.,,
Page 66 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RCS P/T Limits
- 3. 4 .11 SURV~lLLANCE REQUIREMENTS (contlnued)
SURVEILLANCE FREQUENCY SR J.4.11.2 ------------------NOTF.------------------ Only required lo te met during control rod
~lthdrawal for the purpose of achleving er: i tlcal i ty.
Verify RCS pressure and RCS temperature are Once within within the criticality limits specified in 15 minutes the PTLR cased on the current Effeet'.L~e prior to fuitJ".0\4~i f'e~r., f-EFPY-). . . . *, . control rod withdrawal for the purpose of achieving criticality SR 3.4.11.3 ----------------NOTE--------------------- Only required to be met in MO~ES 1, 2, 3, and .q with reactor steam dome pressure
~ 25 psig during recirculation pump start.
Verify the difference between the bottom Once within head coolant temperature and the reactor 15 minule5 pr:essur:e vessel (RPV) coolant temperature prior to each is within the limlts specified in the startup of a PTLR. recirculation pump SR 3.4.11.4 -------------~-----NOTE------------------ Only required. to be met in MODES 1, 2, 3, and 4 during recirculation pump star:t. Verify the difference between the reactor: Once 1":ithin coolant temper:atur:e in the recirculation 15 minutes loop to be started and the RPV coolant prior to each temperature is within the limits specified st:artup of a in the PTLR. recirculation pump {i:.:ootinued) GRAND GULF' J.4-28 Page 67 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RCS P/T Limits 3.4-11 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3. 4 .11. S -------------------NOTE------------------ Only required to be performed when tensioning the reactor vessel head bolting studs. Verify reactor vessel flange and head fJanqe temperatures are within the limits specified in the PTLR. SR 3.4.11.6 ----~-------------NOTE------------------- Not required to be performed until 30 minutes after RCS temperatu~e ~ 60°F in MODE 4. Verify reactor qessel flanqe and bead flange temperatures are within the limit5 specified in the PTLR. SR 3. 4 .11. 7 -----------------NOTE------------------- Not required to be performed until 12 hours .. after RCS temperature~ l00°F in MODE 4.
- Verify reactor vessel flange and head flange temperacures are within the limits specified in tbe PTLR.
GRAND GULF 3. 4-23 Amendment No. ~ ,
- t~J, Page 68 of 173
* <Administrative: Reformatted :page in accordance with ISTS Writer's Guide>
- Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEH (RCS)
~ 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be~ 1045 psig. APPLICABILITY: MODES land 2. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. .Reactor steam dome A.I Restore reactor steam ~5 minutes pressure not within dome pressure to limit. within 1 imit *. B. Required Action and B.l Be in MODE 3. 12* hours assoc*iated Compl etfon Time not met. SURVEILLANCE REQUIREMENTS SURVEJL~ANCE FREQUENCY SR 3.4.12.J Verify reactor steam dome pressure is
~ 1045 psig.
\~ GRAND GULF 3.4-36 Page 69 of 173
--------.. *----~--- *- ....
<Administrative: Reformatted page in accordance with ISTS Writer's Guide> ECCS~bi>.¢r~fiffg
**35J
.:Verity, for *.e~th, E:ca:s inj~cti'on/sp.ray .suhs¥*stem; * * . at :~~y~I*,e,:*.*'!"."":<.~*"°*:~~~.
. locations *susc~p.tibl~ to ga~ :8;¢cµmulatiQrt aie-:: '
**s9fficfehtiyti1tect:wit.q*W~ter;; , . .
">. . .. ;NbTE:: c - - - ***** .. ~ ' .. > .... ,. ;: . : *..
. fNpffequired'tcib~(rn~tf()f*.ststern:yent *.*~ow p'~ffjs *...
A -~:':/ - .
*0,r.1~:11~d u11~.et~~n1t.,tst.r~liye. . 9Q.qit9L . . ..
Verify, e~. 9~ E:~Q§}hj¢:Gfiqrylspr*a,y~yb~y$forrr tn~n~~t,.. .** 3.:t .aay.$\;/**:,-....;-*- -....
'pow~r. :op$ra'te:ct* ~rig:cl:uiom~tic)ialve. 1n*: th~:flowp~th:,.
tha.ti$ .ootJoc~e_qi~ s.~$1$d;. pr:.qtherwlse. ~ec~re.d*Oirl *..... pt,'sil160) J$:, htthe,;,:correcf p6si~fon~ ' . .. Vefity**,$a.oh **ECcs***~LJrnp:.devetopsJhe.***~P~.4rfied .*nbw: :.;.ln*.*a~.9c,r~*a.n~~:*."'itfl\ rate: with.* the $pe:qifiecf ,tot~kd.eveJqp5:?ct .h~aq*~ . . .. ,,'.the JN$J:8VICl;t
**TESTfNG;'. .
ro:;:.0L :.P:~be'RAM DE'.iEiLOPE!D,
.. *M.F2/\E); . .
..tees. . :?***1tt5,gpm* ~* 290:p~ro:
tPGf **~ 74.sn !J°Pni -~. 12$/psi_d*
- HPf:;$.' .* * ~. \f:'f ts'9em ~ 44$': p~id .*
Page 70 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's. Guide>
~,cs -Qp*~:cattq.g .*
3: .. 5 *. ,1 .
- .SIJRV6:r.LLA.Nce iREQUIR'EMENTS-: * (conti nueqJ ~ . ... '... . . . . .. . . . . .** .,., .. *. ,** .
. sDRVE:tLLANc:E *
.; *:F,REQ(fENCY
*:*: .<: *, : .. * * -< N(jfE> * *.* <*. >: ::. :*>**
**V~$s~J inji:fotfoO/$.P.r~y, may b~ .e>ec:Jucfeq.
', *... -._<:,.* ('~:- -~ _.; ;*:*..... *:*. *;._:_' ....-.* _* .. *.... :- *.--:. ~--. ::**.-:- *._. : .. : : f ... *__ .. : . .*:..... .*..::_.- *_ ..... . :* *.-*.: * .. : .-.*
.Y~rff:Y *,e'afh :;4CS.*.**i*hjeCti*Qn1.~*ptay Jub~Y:~*~~~:
*:act;uat;e:S' OR ~in ):lCt:~aT or .si muhrtefcf . .. .. -
alJtomati c .:, 11iJtiat-ton . si.g,na1 . .
;Y,~rf~t::.:t:h,~.*f'Q.S,~ _gC¥Uat~f.cj'9,
,$lmQla,:ed .a...ttpmatTC *lmti:.~t*1 on*
en. ~t:tlJ:aJ :s 1gn al' ..
,or
*,: ::<: .'.<. *.*. *< **N(fl}E,. **.* *.**.*.: .** *., ;.\*: ~* .. :
~<ft\f¢gu}red. to be'.*.Her~crmri~d JJr,t;tl . p.~qtirS: .;
~ft.er> .feq:c:tor *~/tep.rn pressure .~nit 'flow :;;lf~', ..
adeq~~.1::e:* to* p~:fform ..the:.. *1;:e~t~
*
- C......... _
. V~hi<f.v ;eacH.*Apsv~lve .t~Ji~:ft'mode atiuato.t strokes:.' when ,manually, *actuated;r. <* * * * *
* :1-n,~ocoraari,ce-*
.1Jiit'f-i:. 'the * *
'* *.* ... . . :l~S~~Vl~*~TE~;l~G* .*:. . . . , ...
*.PROGRAM I.
* :\J,erj:fy .the:,w~cs. RESPONSE' TIME:
s:ys.te1tr .;~.-* wi:t.hi n limit$~
- for *~* Hl?C~ .*
'.2.4 me,,tl=is.< **'
)
Page 71 of 173
<Insert Page 3.5-5a>
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.1.8 -------------------------------NOTE--------~-------------------- ECCS Actuation instrumentation is excluded. Verify the ECCS RESPONSE TIME for the HPCS In accordance with System is within limits. the Surveillance Frequency Control Program GRAND GULF 3.5-5a Amendment No. Page 72 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
ECCS-Shutdown 3.5.2 ACTIONS (continued)
. CONDITlDN REQUIRED ACTION COMPLETION TIME D. Required Action C.2 D.l lnitiate action to Immediately and associated restore secondary Completion Time not containment to met. OPERABLE status.
AND D.2 In;tiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status. AND D.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5 . 2.l Verify, for each required 1ow pressure ECC$*: J:a'.hf)UfS ~-----~* injection/spray subsystem, the suppression; pool water level is i:?: 12 ft 8 inches. ** \.
\J GRAND 'GULF 3.5-7 Amendment No.***~
Page 73 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
8CCS-Shutdown 3.5.2 SVRVEILLANCF. REQU!REMEN'i'S (cor.tir.ued) S C:RVE I :...:...ANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pre:rnure cq'f.E?- ** *+;+2....,.*--,..... **Ill~.......~~* Spray (HPCS) System 1 the~
- a. Suppression pool water level is
~ 12 ft B inches; or
- b. Condensate storage tank water leveL
~ 18 ft.
SR 3.5.2.3 VQrify, for each required ~ccs injectior,/: spray subsystem, locatlor.s susceptible. t:if
- gas accumulation are sufflcer.tly filled w.i. th water.
- SR 3.5.2.4 --- --- --- --- - -- ----N87~-- -- ------------* ......, ** .*:*
- Not required to be met fer system ver.t f.J;*b\.J paths opened un:for ,:idmir.istrative cor.trol.~-
V~rify each required ECCS i~ject:on/spr,y subsystem ma~ual, po~er operated, and automatic valve i~ the flow path, that .I.'~. not locked, sealed, or otherwise secure4f position, iS i~ the correct position. *
- GRAND GULF 3.5-8 Amendment No.~' ~ , '?~2, Page 74 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
ECCS-Shutdown 3.5.2
. SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY
)
SR 3.5.2.5 Verify each required ECCS pump develops the specified In accordance with
. fl?\!J~\~ *~il~ tne *~pecifieg *.~Q~c:11* dey~\gp~~*h~~d;.
..................................,;,; ;,; ;,; ; __~. ;,SYSTEM<
- .. - T,QTl\L.
- <fJE\iEkC>HEtiHEAti * .
~. 1; **
t.tl.~JN§~~y1cr:.* TESTIN§: . PROC3RAM' *. **.i*. ,'***,
- t.*. .*.*.***.*.'.....*.: \
_::u.ecfa::*** .ti!:t1hsigptfi . *~:-29oJ,skt *
, iP:crff **:~:14stj'gpm, .*.. ~'t~sJ,si4>:
'HPG$: .*:~:o11ts gpm* * -~.A4s,p.sia.: .
- '.":'.*~*. . :_ .;~~*-:.:~.err~.:.>*--*** . *. *-.***: ... * -. . . **
- 0
.. iVess~I inj~~UQn/spr~y m~}"bE;l::E:!xclU.d$Q;-*
-,;*:< "'*;. *'* .. ** - . . . .-* * ...... * . ,.,*- ..... * ,..,_. ,* ,* .. **:*.\
**.-:-.** .. * , . ' .::**.*.,::::*.:* *:* * *.:"~.-*,._--._- .. * . * * * .-.~ ,.,,_. . . . . . * * * * ' *
- _, . * - ~ ~ : .. '.-. . * -. ***** --*. * - * * *. ,.* * **.. * .*., i_.
*.v~tif9/~acnit~quir#d.:~c9~.:inj~stiot11spt~y;;syqsy~t~hl;-
actuates\on
.s,grtaL. '. * , :an** 'acmar:or.. " * ** *
- simulated , * ** :autorriatie:in * * ** * * * ,
- itiatioh *. * * *. -,
GRAND GULF 3.5-9 Amendment No. -l-331 W;*gn; Page 75 of 173
<Administrative: Reformatted page in .accordance with ISTS Writer's Guide>
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas accumulation are sufficiently filled with water. SR 3.5.3.2 -------------------NOTE------------------- Not required to be met for system vent flow paths opened under administrative control.
--------------------------------------- *~*.
Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. SR 3.5.3.3 -------------------NOTE-------------------- Not required to be performed until 12 heurs after reactor steam pressure .nd flow .re adequate to perform the test.
./ ..*.
Verify, with RCIC steam supply pressure *,*.,.
~ 1045 psig and~ 945 psig, the RCIC pump can develop a flow rate z 800 !Pm against a system head corresponding to reactor pressure.
SR 3.5.3.4 -------------------NOTE-------------------- Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with RCIC steam supply pressure ,i4 moritfip .*'4:~I!-*-.*. ---1
~ 165 psig and~ 150 psig, the RCIC pump can develop a flow rate~ 800 gpm a,ainst a system head corresponding to reactor pressure.
. . {continued)
In accordance Vvith the Surveillance ..., ......
~
Frequency Control Progr~m ...* GRAND GULF 3. 5-11 Amendment No. ~' ~, *~ Page 76 of 173
<Admini~tr?ttive: Reformatted page in accordance with ISTS Writer's Guide>
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY
- SR 3. 5. 3. 5 -* *- - - - - - - - - - - - - - NOT.E - ~ - - -- - - - - - - - - - - - - - - -
Vessel injection may be excluded .
** . : I
- ! *. ; I Verify the RClC System actuates on an
.. :\:*. **. -
actual or simulated automatic initiation
*** 1 signal.
- I *\
; I *
- I*
.GRAND GULF 3.5-12 Amendmen~ No. 420. TQ.W Page 77 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Primary Containment Air locks 3 .. 6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 ----~----*~---*-*-NOT ES*-------********-*
- 1. An inoperable air lock door does not invalidate the previous succeisful performance of the overall air lock leakage test.
- 2. Results shall be evaluated against acceptance criteria of SR 3.6.1.l.l in accordance with 10 CFR 50, x
Appe.ndi J .. as modified by approved exemptions. Perform required primary containment air In accordance lock leakage rate testing in accordance with 10 CFR 50, with 10 CFR 50, Appendix J. as modified Appendix J, by approved exemptions. Testing Program - The acceptance criteria for air lock testing are:
- a. Overall air lock leakage rate is s
- 0. 05 *La when tes'ted at '.t!. Pa.
- b. For each door, leakage rate is s 0.01 La when the gap between the door seals is pressurized to~ Pa.*
SR 3
- 6 .1. 2
- 2 Verify primary containment air lock seal ,.,#,~::Y.s:?"':;-.*****.--*.......................*-...
air fl~sk pressure is '.t!. 90 psig.
***= *.*
GRAND GULF Amendment No. ~ l:l:~~,') Page 78 of 173
*~ .. "\... . .<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
I II: 1':
- Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS continued
..... SURVEJLLANCE FREQUENCY
- .**.. . * .- .* . . . s*R . 3 . 6 :* 1 ; .{ 3 Verify onry one door in the primary
... '..:._,-;_:\*_**.::" .. **..:.*.* .* containment air lock can be opened ~t $: time.": *
- SR 3 .6 .1 . 2 . 4 Veriry, from an initial pressure of
-.. <*... -~ ' 90 psig, the primary containment air lock sea I pneumatic system pressure doe$:,
- **. *. not decay at a rate equivalent to
> 2 psig for a period of 48 hours . /'*
I ,f,,,
- I GRAND GULF 3.6-8 Amendment No. 4-4-21 :f9¥.
Page 79 of 173
. ~ . .
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
PC IVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY u I SR 3.6.1.3.1 ------~~*------~-~NOTES-~-p------------*-
- 1. Only requ;red to be met in MODES 1, 2, and 3.
- 2. Not required to be met when the
* ?O:: J,~.~ pri~~!Y ~9~~.ai.1i.tr1~n,t p\lr.9e .
vMves. :ate .gpen '.fo1t; .tessijr~\to~trol,
-- .' > *, 9r a,r qw1 J '*. ~.onsJcl~r,~tions r~r. -per._so)1n*e1_* entry~.:. AT$e,~ . ~et.,
. required to be met during Surveillances or special testing on the.purge system that requires the
*'Y,,IY~~,.i~'.p-.:.~tRJ>~Q.+.-* -~ *. 0J!1~~s
- sh:~Tl .noi . *;b~..9JJ:t~*,::: . ,4ith.**~.the);6 inch
<primarr contafomerit purge* :'or the drywell vent and purge supply and exhaust lines open.
Verify each 20 inch primary containment purge valve is closed. *
- SR 3. 6.1.3 .z -----------~~-~~~-NOTES--*---~-----------
- 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
- 2. Not required to be met for PCIVs that are open under administrative controls .
Verify each primary containment i sa 1at ion :.' ~1 . .:cl.'.a~:.t_ -~----iiii..* manual valve and blind flange that is located outside primary containment, drywell, and steam tunnel and not locked, A?, sealed, or otherw;se secured and is
- _*..¥..:
required to be closed during accident conditions is closed. (continued) GRAND GULF 3.6-14 Amendment No.. ~ ,::~,;at
,*.JMN:,:a]:"2ooa:::;
Page 80 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
PC I Vs 3.6.l.3 SURVEILLANCE REQUIREMENTS (continued) u SURVEILLANCE FREQUENCY In accordance with SR 3.6.1.3.5 **-----*--*~---*--NOTE------------*------ Only required to be met in HODES 1, 2,
- the Surveillance and 3. Frequency Control
, Program Perform leakage rate testing for each ***-~:~1 :;rri*~.~.$h;s'_:*:~_-_.,*
primary containment purge valve with *at*l.east 2:,: ..._*.-*_*. *. .. . *. . resilient seals.
*i:;t:~ij!\.~:!;fi**11--~~*
J.A&Fi1:hs:: In accordance with 10 CFR 50, Appendix J, Testing, Pro.gram tNOTE :
. *;/*
**;~ND ~
\ ----~ ~-~:-4_-N.8te*.;._:~_;,~ .......
Not appiic-.ible to valves tested witMn 92 days prior to any purge valve failing to meet its acceptance criteria Once within 92 days, test all remaining purge valves, if any purge.valve fails to meet its acceptance criteria (continued) GRAND GULF 3.6-16 Amendment No. ,l,20 ~ ;.*1"3&*,
; APR'. 6.,.6*J9SB
- f:.O.-:.,-
Page 81 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
PClVs 3.6. 1.3 SURVEILLANCE REQUIREMENTS (continued) SURVErLLANCE FREQUENCY SR 3.6.1.3.6 Verify the isolation time of each MSIV is~ 3 In accordance with seconds and s 5 seconds. the JNSERVICE TESTING PROGRAM
*.,,.I'.._:*.
- SR 3.6.1.3.7 Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal.
SR 3.6.1.3.8 -----~------------NOTE--------------------- .- :. . ": *' Only required to be met in MODES 1, 2, and 3 . Verify leakage rate through each main steam linEi. is~ 100 scfh when test at~ Pa, and the total leakage rate through all four main steam lines i~:~ 250 scfh when test at~ Pa SR 3.6.1.3.9 ------------- . --..--NOTE--~-------------------:.*:. . **.**:. Only required to be met in MODES 11 2, and 3 ... Verify combined leakage rate of 1 gpm times tti~ : .* ~> ..*.* .*.*. ,.'. .*. *. . ,. total number of PCIVs through hydrostatically . . <:ffn:.§iq99.r~M¢e *.. tested tines that penetrate the primary containm~n\ ", :Wittr::1,() O.F.R§P~ is not exceeded when these isolation valves ar~: ; ,A.pp~ndi*,':JI . tested at~ 1.1 Pa. .. '.t~stlngJ?rqgrar:rj lri accordance With
- the Surveillance Frequency Control
- Progr~rn-GRAND GULF 3.6-17 Amendment No. 44-al m.*~.1.t ,
Page 82 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Primary Containment Pressure 3 .. 6.1..4. 3.6 CONTAINMENT SYSTEMS 3.6. L4 Primary Containment Pressure LCD 3.6.1.4 Primary containment to auxiliary bu;lding differential pressure shall be c!: -0.l psid and :s 1.0 psid. APPLICABILITY: MODES 1, 2, and 3. ACTIONS I CONDITION REQUIRED ACTION COMPLETION TIME
~
A. Primary containment to A. I Restore primary l hour auxiliary building containment to differential pressure auxiliary building not within limits. differential pressure to within limits. B* Required Action and B.l Be in MODE 3. 12 hours
.assoc;ated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify primary containment to auxiliary building differential pressure is within:
limits. \. u GRAND GULF 3.6-18 Amendment No . ~ Page 83 of 173
<Administrative: Reformatted . page in accordance with ISTS Writer's Guide>
Primary Containment Air Temperature 3.6 . 1.5 ~ 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Primary Containment Air Temperature LCO 3 .. 6.1.5 Pr;mary containment average air temperature shall be :s 95°F .. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.l Restore primary 8 hours average a;r containment average temperature not within air temperature to limit. within limit. B. Required Act;on and B.l Be in MOOE 3. 12 hours associated Completion
- Time not met. AND B. 2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3 .6. L 5. I Verify primary containment average air temperature is within limit.
GRAND GULF 3.6-19 Amendment No . *te~t Page 84 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
LLS Valves 3.6.1.6 SURVEILLANCE REQUIREMENTS
- . FREQUENCY .
**: . SURVEILLANCE 1
*** ** : * *- SR 13*. 6. 1 . 6. 1 ------------------NOTE-*---------~-------
* * "'.*,, I Not required to be periormed until 12 hours aiter reactor steam pressure and flow are adequate to perform.the test .
Verify each LLS valve relief-mode actuator strokes when manua *' f y act.uated.
- iii!i!!frz:::ffl .
on a STAGGERED TEST BASIS for each vajve solenoid
- .:..
- 1. : *
. . SR 3-. 6 . l. 6 . 2 . - - - - - - - - - - - - - - - - - -NOTE - - - - - - - - - . - - - - . - - - -
Valve actuation may be excluded.
- .* :*. *-. Veriiy the LLS System actuates on an . *.. * *"""2:"6o~/~~~-....-----....
~ I
- I * ;, :
- actua I or s i mu Iated automat i c i n i t: i at i :o*fr signaf. ,, :'
,*'., *; I
~ :- . . :._
**. - :- \ ,..
GRAND'GULF 3.6-21 Amendment: No .
- Be, ~.$.?;'
Page 85 of 173
<Administrativ e: Reformatted page in accordance with ISTS Writer's Guide>
RHR Confainment Spray System 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 ---------------~- ---------~r-JC> "fE-------~-~--f f~--~----
- 1. RHR containment spray subsystems may be considered C>PERABLEqµ~it19: ...
alignment and operation tor*.pe~c:iyfl}~it' In accordancew ith removal when below the RHftcuti~,.': ._ ....-.* *the Surveillance permissive pressure in Mqp'gi§Jf~~p~ble : frequency Control
<Add a line space.>~ ._ . .t>to$il'.l9..'11c1nually realignecJ::ciod:n,o.l:.' .... - Prograrrt._._............. -.. -.......*... c,
- ~ ojll~[WiS~ irio,~erable. . * ._ . . . __ .*. _ . _.. ,/l\_,,._...........,....,.....,.....,.......,iiii-1_/
-*:2*; :*.~ot~~*guir~~~~o be met for_$~$terf1.y~rlt-.
*:;!'~~;'.p*atn¥t,pened under adfninis~rativ'e'i t(r~9uire~: [: . .. _* .: * ~\~~:col '. .:*-* . ----------._-* .... . ~- - *. *. >*
Verify each R HR containment spr~y;~y~~y~t~qr manual, power operated. and autqn:iEiticf.v~hi¢Jfa the flow path that is not locked. se~i~g/ot*. . otherwise secured in position is in-thl(correct position. * * * * -* SR 3.6.1.7.2 Verify RHR containment spray sub$y~1~1'rj\lqp~tiQQ$:: . susceptible to gas accumulation a(e,'~uffl¢i~ot li . filled with water. * **
- SR 3.6.1.7.3 Verify each RHR pump develops a-~_oWra~~::c,>f:.
?. 7450 gpm ori recirculation flow th(<:>vgh*tt;lef, **r~Qf~~ht~*.
associated heat exchanger to the ~pppre~$19F):., * *y.,ith~fl~: :, / . . . pool. -********* **** ****. * )N$'EB\IIC~ .
'JEstrNG,. **. .Jr.
,_-)?_,._,_:_.*.
*,P~GGB~M* -
SR 3.6.1.7.4 Verify each RHR containment sprc:1~.$9~§YSt$rn" : .** ;;~*4;*;r;t1~'~t*~:~:{-E*.~.........------.... automatic valve in the flow path a¢tµ?t~§J9Jt§'*
- correct position on an actual or siml@t<::!9' .
automatic initiation signal. ..................*~-~~!"'"II**"':**
.......~~ ........................~ ;
Verify each spray nozzle is unobsti"Lt¢j~¥ 3.6-23 Amendment No.~ . .:1-W, ~V?{1i; >:~~..........~.'.Format: Move SR 3.6.1.7.5 to new Page 3~6-23a.
- Page 86 of 173
<Insert new Page 3.6-23a>
RHR Containment Spray System 3.6.1.7 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.1.7.5 Verify each spray nozzle is unobstructed. At first refueling In accordance with the Surveillance Frequency Control Program GRAND GULF 3.6-23a Amendment No. Page 87 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
FWLCS 3.6.1.8 3.6 CONTAINMENT SYSTEMS
- 3. 6. 1. 0 Feedwater Leakage Control S ystero ( E"WLCS)
LCO 3.6.1.8 .Two FWLCS subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. A.CT IONS CONDITION REQUIRED ACTION COMPLETION TIME A. One FWLCS subsystem A. l Restore F'WLCS 30 days inoperilble. subsystems to OPERABLE status. B. Two FWLCS subsyslems B.l Res Lore one FWLCS 7 days inoperable. subsystem to OPERABLE stalus.
- c. Required 1\.clion and C.1 --~---NOTE---------
associated Completion LCO 3.0.4.a is not Time not met. applicable when enlering MODE 3. Be in MODE 3. 12 hours SURVEILLANCE REQUIRr.MENTS SURVEILLANCE FREQUENCY SR 3 . 6 . 1. 8 . 1 Verify RHR jockey purop operates prope,tl.y;;.. GRAND GULF 3.6-24 Amendment No. ~ ' .~t9*1: , Page 88 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
MSIV LCS 3.6.1.9 3.6 CONTAINMENT SYSTEMS 3.6.1.9 Main Sr:eam Isolarjon Valve {MSIV) L(~akage Control Syst.em (LCS) LCO
- 3
- 6
- 1. 9 Two MSIV ,LCS s'.1bsy:sterr.s shall be OPERABLE.
APPLICABILITY: ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIV LCS subsystem A.1 ResLore MSIV LCS 30 days inoperable. subsyslem to OPERABLE stat:.is ..
- 3. Two'MSIV LCS a.1 Res~ore one MSIV LCS 7 days s~bsystems inoperable. subsyscem to OPERABLE status.
C. Requi~ed Action and C. l -------NOTE------- associated Completion LCO 3.0.4.a ls not Time not rr.et. applicable when entering MODE 3. Be in MODE 3. 12 hou.rs SURVEILLAtKE REQUIREMENTS SURVEILLANCE E'REQUENCY SR 3.6.1.9.l Ope.rate each o~tboard MSIV LCS blower~ 15 minutes~
\(99,~t,i 114~,ilf ..
hi accordance with the Surveillance
- Frequency Control
*Program.
GRAND G.lJLF 3.6-25 1\mendment N o . ~ ~ t : ,,.*,.....
~ ,. ,,
Page 89 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
MSIV LCS 3.6.1.9
* .. i -*
.:. - SURVEllLANCE REQUIREMENTS continued I**,
I *" ,* SURVEtLLANCE FREQUENCY
,*' .. *
- SR ~ :_ .*-.*_*. **_* *_, >
*3: 6. 1 . 9 .*.*-~.*.*..* .*****.*~****.
_._ ~<* _*. *.
-. MS IV LCS asubsystem.
Perf'orm system f'unct. i ona I
. . .}(:.~ i..... 1 . . .
- o ~ '*
- I I
- i. .. . ~ ;. ** *
- I* .. * ,t I I } I
* ."GRANO GULF 3.6-26 Amendment No. ~ ... 4$~:;
Page 90 of 173
i ~Administrative: Reformatted page in accordance with ISTS Writer's Guide> Suppression Pool Average Temperature 3 . 6.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3 .6.2.1.l Verify suppression pool average .: :24 ::h:~~-¥~("4:'~~~ temperature is within the applicable limits. )\ND.. GRAND GULF Amendment No. J2.f);';; Page 91 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be~ 18 ft 4-1/12 inches ands 18 ft 9-3/4 inches. APPLICABILITY: HODES lt 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A-.1 Restore suppression 2 hours level not within pool water level' to limits~ within limits. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met . AND B.2 Be fo HOOE 4. 36 hours SURVEILLANCE REQUIREMENTS
*SURVEILLANCE FREQUENCY SR 3. 6.2. 2. l
- Verify suppress ion pool water 1evel ;s within limits.
GRAND GULF 3 .. 6-30 Amendment No. -~,;- Page 92 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
RHR Suppression Pool CooUng 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling a1,*;~g_Y~-' ;.~.........~---1 subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, pt*
- otherwise secured in position is in the correct position or can be aligned to the correct pos itior, ~
SR 3.6.2.3.2 Verify RHR suppression pool cooling subsysten,* ,@f._day~:.*_____...,.., locations susceptible to gas accumulation are *.
- sufficiently filled with water.
SR 3.6.2.3.3 Verify each RHR pump develops a flow rate ::1n~,cc9r.g~r\q~'Y:Jith. 2 7450 gpm through the associated heat
- the,IN§l.:RYIQE exchangers to the suppression pool.
iltl~l~ . \ t. Irr accordance with'. *
- the Surveillance Frequency Control
. Program GRAND GULF 3.6-32 Amendment No. ~ . ~;;g,t1,.
Page 93 of 173
Writer's Guide>
* : * * *<Administrative: Reformatted page in accordance with ISTS
- .* ...* SPMU System
*3 .6 .2. 4
*SURVE I LLANCE REQU I REMENTS SURVEILLANCE FREQUENCY Verif y upper _containment pool water leve)
-is i 23 f't 3 inches above the poo I I 1,*
- .** bottom.
' * 'L"' * *
*. Ver i fy upper cont a i nment poo I water tempe rature is~ 125°F .
' * * 'I I*
- I: I *I ~ : ~*' * * * * "'
Ver i fy each SPMU subsystem manua I
- powef 1
*opera ted. and autom atic valve that is riot, I ocked ,* sea\ ed, or otherw ise secur ed in*
- posit ion is in the corre ct posit ion.
0
-"'. *,N t ,<:_."* ..;,:.*,,;* ..:~_,_--~:::f_
.*,;::*** 7
.*_;;ij_.~_- r.* , ..e_'. ,A_._._.*_*_,*.tj_:_:._*__
- _*_r_
"1
*.*_ .e_*_*_*_**_ffi_:_.e_:_*. *~-.t_i_
._]_i_r_ ****~- :-a_
.. :;'._*.:$_'._R_:_._*
*. :~---*_--_*:_-_*_*~_-* *-.*:~.*--. :l_:s_._*
1 *
~_'__ .**a_ ._rr_~_*-_ :_._i:>~;.
uppe'r * * *
*_*::_*-_-_;_fl_.
- ..._:* _ () _ _
-* *tE?qu ired- t:o'; oe'imet wherr*a *r conta inmen t pool levels are maint ained
- per SR 3.6.2 .4.1 and suppr ession pool .. ~
water level is maint ained ~ 18 ft 5 1/lZ.
-- . inches {one inch above LCO 3. 6. 2. 2 Low: -
Water Leve I ) .
- - -- - - - - --- - - - - -- - -- - -* --- - - ----- - - - - - - ' ...~
Verif y a I l upper containment poo I -+3*1- f o f f , ~ __. . . ,.........._ _.....,. gates are in the stored positi on or are:
~ ..
otherw ise removed from the upper
~*. *.
conta inmen t pool . 3 .*6 . 2 . 4 . 5 . ------- ---.--- ----NO TE--- ------- ---*--. --.":-- *::*. SB. Actua I makeup to the suppr ession poo I m~~*
- be ex~ Iuded . * ..
verif y each SPMU subsystem autom atic vatve 'actua tes to the corre ct posit ion
*: - . ~ : *'," an actua l or-sim ulated .automatic initia tion*~ ignal .
In- accordance-with * *
.: ,* *' the Surveillance
- Frequency Control *
- .* 'Program
u ' 1* \ .. J.
'W/.
Page 95 of 173
*<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Primary Containment and D~ywel I Hydrogen lgnit~rs 3.6.3.2
- . ..... _. :. :, * -ACTt ONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME . .*..-_: . _'(_* _ :. *.....:. ' c... Requ i r-,ed Action ar:1d C .1 Be in MODE 3. 12 hours
- * * *
- associated Comp I et ion
* *
- Time not met .
*suRv*E I LLANCE. REQU I REMENTS SURVEILLANCE FREQUENCY
*.* * *. *. -**. -SR. . 3 . 6 . 3 . 2 : 1 Energize each primary containment and .- lBl'days ..*-.-.- -.......
drywe I I* hydrogen igniter division and perform current versus voltage hI * '. * *:I . ; *, ._ measurements td verify requ i red igniter$>
' I,' ,* fn service. ~
SR . 3 . 6 . 3 . 2 . 2 ------------------NOTE----------------~, Not required to be performed until
. - :* '* 92 days after discovery of four or more igniters in the division rnoperable.
--------------------------------------~ -
Energize each primary containment and :-<ttQr?~---
. *a::J"'lj~+p,;:,j~......-.~~1*.
**de11:
drywel I hydrogen igniter division and perform current versus voltage me~surements to verify required igniter~ in service .
. *~ . .
- I** * : I .-~ *
- * * *. SR '3 . 6 . 3 . 2 . 3. Verify each requ .ired igniter in inaccessibJe areas develops surficient current draw for a~ 1700°F surface temperature.
- * . 'GRANO GULF
' \
3.6-38 Amendment .No. +29 r -t~.iF I Page 96 of 17~
<Admi~istrative: Reformatted page in* accordance with ISTS Writer's Guide>
Primary Gontainment*and Drywel I Hydrogen lgnitors
*,: 3.6.3.2
,"':!': :* I,*"
- I
** _;SURVEILLANCE REOU I REMENTS cont i nued
,II .**:: SURVEILLANCE FREQUENCY SR *3.6.3.2.4 Verify each required jgniter in accessfble areas develops a surface temperature of~ 1700°F.
\
*' *- .**=*==========================.:::::::::!:::::::;::::::::::::::::::;::==========-==
",,.
- I I ~ .. ' *
- I
" !. I *
- , * ' ~,I ", I ' " * * *
* :. ~ =.
*,* :.= ' ,*
.
- GRAND GULF 3.6-39 Amendment No . .4z-0. , ~,";
Page 97 of 173
', I I
<Adniinis~rative: Reformatted page in accordance with ISTS Writer's Guide>
DrywelJ Purge System 3.6.3.3
.SU'RVE I LLANCE REQU l REMENTS SURVEILLANCE FREQUENCY
*.*.* ~~ 3.6.3.3.1 Perform a CHANNEL FUNCTfONAL TEST of tl1,E3>
' * * ~*. ' * ' * ', ' I :
isolation valve pressure actuation instrumentation.
*... : * ,* *.. SR 3 .-6. 3. 3. 2 Operate each drywell purge subsystem
. *,**. i 15 minutes .
Ver i-fy each drywe I I purge subsystem flow rqte is~ 1000 cfm. SR 3.6.3.3.4 Ver. i fy the opening pressure different i-~J of each vacuum breaker and iso Iat ion. *
.. valve is s:1.0 psid .
,: . GRAND .GULF 3.6-41 Amendment No. +ze, J~?~ Page 98 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Secondary Conta;nmcnt 3.6.4.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME u
- c. Secondary containment C.l --------NOTE---------
inoperable during LCO 3.0.3 is not movement of recently applicable. irradiated fuel assemblies in the
~~~~-~***~~*-~-------
primary or secondary Suspend movement of Immediately containment or during. recently irradiated OPDRVs. fuel assemblies in the primary and r- secondary containment. AND C.2 Initiate action to Immediately suspend OPDRVs. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3
- 6 *4 ~ 1. l Verify all auxiliary bundj)ig ~J.td*** ..... _ . "--~i~:'.*a~i1
~ -...............
.enclosure building equipm'~1i:t-_h~tc:.hes.; ~ncf.,
blowout panels are closed . and: $ealed...
- SR 3.6.4.1.2 Verify one auxiliary buildfn.g: a6d *.* * ....... * *.:*
*\*** *,.
{} enclosure building access.:-door Jn :e.:a~h*:. access opening is closed, e?Cc~pt-.:w~en. :,f.het -*.*. *.*i.*.**_* _*.*_. .*:.*_.....*
'.'..-.1 access opening is being q~~d,for el'lt'ty and exit. - *
- GRAND GULF 3.6-43 Page 99 of 173
' <~dministrative: Reformatted page in accordance with ISTS Writer's Guide>
Secondary Canta i nm.ent 3;6:4.1
.. . .. SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.4;1 .3 Ver i 'fy the secondary containment can bEL drawn *down to ;;? o. 25 inch of" vacuum wate'r gauge i_n ~ 180 seconds using one standby
. ~~~1~l~Ee~.~,* * *
*-*1;1:.§J :.,~~~:ts~ 15ott
.. gas treatment (SGT) subsystem. -. :~c:1pb
.sq:r
~~~?i~!:~~:* ,
SR 3 .-6. 4. 1 . 4
- Verify the secondary containment can be, maintained;;? 0.266 inch of vacuum water
*gauge for 1 hour us i ng one SGT subsysterrr
**.!~~~ti:fc;>r,:*;~~;******
~§J?,* ~ *98 :?l'li at a flow rate~ 4000 cfm. :$~T* spij::1y,$~om::
- j ~ *:.
I O : i ,, ., . *.'
.',*I GRANO GULF 3.6-44 Amendment No. 469. J:;p,J, Page 100 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
SC IVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 - - ~ ~. . 4
~-~*-*--*w---**---N OTES-- -*-*-*---- ---------- ----
- 1. Valves, dampers, rupture disks, and blind flanges in high radiation areas may be verified by use of administrative means.
I
- 2. Not required to be met for SCIVs that are open under administrative controls.
Verify each secondary containment isolation manual valve! damper. rupture diskl and blind .... flange that is required to be closed during accid~!1 ( condition s is closed. * *
- SR 3.6.4.2.2 Verify the isolation time of each power operated,. -
automatic SCJV is within limits. SR 3.6.4.2.3 - Verify each automatic SCIV actuates to the isolation position on an actual or simulated automatic isolation signal. GRAND GULF 3.6-48 Amendment No. .:t.GQ, 4-Q+i g:~.L Page 101 of 173
<Administrative:. Reformatted page in accordance with ISTS Writer's Guide>
~GT System 3.6.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3 .l Operate each SGT subsystem for
~ 15 continu ous minutes with heaters operati ng.
SR 3.6.4.3 .2 Perform require d SGT filter testing in .:ffrJcc:ordahce accordance with the Ventila tion Filter, wi'.tfr tn{,Vffe. Testing Program (VFTP). SR 3.6.4.3 .3 Verify each SGT subsystem actuate s on -ci:tr: . i-t:f4..,.'>--- - E ~ -.... actual or simulat ed initiati on signal~ 3.6-51 Amendment No. li'e, -3:9r,: ?9~,: GRAND GULF Page 102 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
DryweU 3.6.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1.1
- Verify bypass leakage is less than or equal.to the bypass Jeakage limit.
However, during the first unit stEirtup following drywall bypass leak rate**** testing performed in accordance with '. this SR, the acceptance criteripn/i( .. leakage :s 10% of the bypass**1eakage* . limit. * ** *
. two 48 .morithsfoUowing a test with bypass leakage greater than the bypass leakage limn AND
---*-NOTE----
SR 3.0.2 is not applicable for extensions > 12 months.
._*_: . *~ .........:. : /. . .:.: ( . :
. : -~- . " - .. . . .."*
* **~ 1.x2'.o ffl.o.p.tM,.,.*. *. .*~~e~tit~~!*.*.
#le-n~xt':g,yw~n ,l:>ypas~ .
**.*.1$~.k*. rate\*~~st.P~.rfC>~rp$d. **
- .aftE3r:the*,9°:!9~~r .*:19i.* '.?.09a **
****te.s.t*.*.~.h~.11:*:~iip~rfC>(rl}~g.**,n9**.*
- .,~J~rtb~n~.u,,~-plali~ r~st~tl .*.
** attef'thp.:EndofGycle:**22 .
*R~f4elinlf G;)yt~~e: * *.*.*
GRAND GULF 3.6-53 Amendment No.~, 494, ~',.21:4,
*VVith Csrreetien better ef 9.'16/96 Page 103 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Drywe1 l 3.6.5.1 E_R_Eo__u_1R_E_M_EH_T_S_(_co_n....,t1.....n.....u_ed__)_ _ _ _ _ _ _ _.,__ _ _ _ _ :f _su__R_V_£I_L_LA_N_C__ SURVEILLANCE FREQUENCY SR 3.6.5.1.2. Visually inspect the exposed accessible Once prior to 1nter1or and exterior surfaces of the performance of drywe11. each Type A test required by SR 3.6.1.1.1 SR 3.6.5.l.3 verify drywell air lock leakage by *: 2A:
.. 'msnths,-**
~--'*.**----:*.
***~**
performtng an air lock barrel leakage test at~ 3 ps1d.
*tt)e Surveillance .~ .
F/equency Control Rmgran, .. GRAHD GULF 3.6-53a Amendment No~*-:* r, Page 104 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Drywell Air Lock 3 . 6.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.2.1 Only required to be performed upon entry tnta drywel 1. .,
~' Verify only one door tn the drywell afr *.*. ,~-~J1e,'",~.~~ 1 lock can be opened at a t111e.
~**
\ v GRAND GULF 3.6-57 Page 105 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Drywell Isolation Valves 3 .. 6.5.3 ~ SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6 5.3.I --*- . . --------- .. --.. NOT**
- i~ . . ;...; ......... -----------
r *; !-?.*.*
..:. _ ot required to be met when the drywell
. ****~
- :1*. > :>:purge supply or exhaust valves are open
._:_.'.._._.N
* - * * *for pressure control, ALARA, or air quality consideratie>l'lS:forpersonrgJ:
~n*~ry~ . *,A1 ~-a, ,n~t:~~ req~ttecJ tQ. be. mf:!t :
dur.ing*, ,urvejllan~es::or sp~c,a.* .**. e~ ]Jig*.
,on . *e.j:,t1rge system th ':r-e,*q1Jires *the'
- valves lo be.**opei'h *. ff~~<~ry,,ell p1.1rg*e*-
supply or exhaust valves shall not be
- ~p~ri
- jrj: . .. . .* ;1 and 2 with the 6 inch or
*..---...... <20i tne ;,_, *rim~ry containment purge system
._................. ::,purge s:upply and exhaust Hnes open .
Verify each 20 inch drywell purge isolation valve is closed.
*SR 3.6.5.3.2 -------------.. -..... -NOTES . . ~---------.. -.. --..;.-*. .:*
- 1. Valves and blind flanges in high
- radiation areas may be verified by use of administrative means.
- 2. Not required to be met for drywell isolation valves that are open undjf~
administrative controls. , *
-------------------------------------- --~.
Verify each drywell isolation manual valve and blind flange that is required, . .* !Ki:,J.~[MQDE 2 to be closed during accident conditions* or *3 *from*
- is closed. .. *. MOP~: *4:*, : if r.1<>-f'.
*P.E!rform,ep *.:1.n
. -"t;fie*J>r.ev..ioY.$>
9? .*:days * * ** GRAND GULF 3.6-60 Amendment No.*--~ Page 106 of 1'73
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.5.3.3 Verify the iso,ation time of each power operated, ,n accordance automatic drywell isolation valve is within limits. with the INSERVICE TESTING PROGRAM SR 3.6.5.3A Verify each automatic dryweU isolation valve actuates to the isolation position on an actual or simulated isolation signal.
- In accordance with the Surveillance F,requency Control
*. Erogram .**
GRAND GULF 3.6-61 Amendment . No. +89, 4-97/~ Page 107 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Orywe11 Pressure 3.6.5.4 3.6 CONTAINMENT SYSTEMS 3.6.5.4 Orywell Pressure LCO 3.6.5 .. 4 Drywell .. to.;.-primary containment dtfferenthl pressure shall be~ *D.25 ps1d ands 2.D psid. -~ APPLICABILITY: HODES 1, 2, and 3 .. ACTIONS CONDITION REQUIRED ACTION COMPLETION TlHE A. Drywell*to-primary A.1 Restore drywell-to- 1 hour containment primary containment differential pressure differential pressure not within limits. to within limits. B. Required Action and 8.1 Be in MODE 3 .. 12 hours associated Completion Time not met. Atill B.2 Be in MODE 4. 36 hours SURVEJLLANCE REQUIREMENTS SURVEILLANCE. FREQUENCY SR 3.6 .. 5.4.1 Verify drywe11*to-primary containment differential pressure is within limits. GRAND GULF 3.6-62 Amendment. No *. ~*-. ****~ ,
*~'ci~,t'\~
-- -. -**- .......... -~--- ----*----* ----- ...... _________ Page 108 of 173 ...,
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Drywell Air Temperature* 3.6.5.5 3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.5 Drywell average air temperature shall be::;: I35°F.
')
APPLICABILITY: . MODES I, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.l Restore drywel 1 8 hours temperature not within average air limit. temperature to within limit. B. Required Action and B.l Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.5.l Verify drywell average air temperature i;$* . :~::2*~::* ~*t>,'a.~s:.,<E.~ -...... within 1imit. \ . u GRAND GULF 3.6-63
- Amendment No .. :le"~::;
Page 109 of 173
<Administrative: Reformatted page tn accordance with !STS Writer's Guide>
i" Drywel t Vacuum Relief System
. *. 3.6.5.6
- _*SURVE f LLANCE REQU J'REMENTS SURVEILLANCE FREQUENCY
-----------------NOTES-------------------
- 1. Not required to be met for vacuum
.breakers or* isolation valves open during survei I lances.
- 2. Not required to be met for vacuum breakers or isolatioD valves open when performing their intended function .
Verify each vacuum breaker and its
- -_: I: I ::"-: :
associated isolation valve is closed. .... *.
... ,,': ... ,.** I
*. 1*:*
.. SR 3 . 6 . 5 . 6 . 2 Perform a functional test of each vacuum breaker and its associated i so I at ion * *
.valve. ...*
SR 3:6.5.6.3 -Ver, fy the opening pressure di r'ferent r a*f of each vacuum breaker and isolation valve is~ 1 .a psid.
\. In accordance with ,
*.*; 1" *'.
the Surveillance ~ _
- Frequency Control
- Program i ***
GRAND GULF 3.6-67 Amendment No. ~ . :~:, Page 110 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
SSW System and UHS 3.7.l ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One SSW subsystem -~-~-----NOTES----------- inoperable. ]. Enter applicable Conditions and Required Actions of LCO 3.8.1 1 "AC Sources-- Operating," for diesel generator made inoperable by SSW. 2*. Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal {RHR) Shutdown Cooling System-Hot Shutdown, for RHR shutdown cooling subsystem made \ . inoperable by SSW. v D.1 Restore SSW subsystem 72 hours to OPERABLE status.
. . **~~****'° Format: Move ACTION E from following page .
(continued) GRAND GULF 3.7-2 Amendment No. lea:; Page 111 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
SSW System and UHS
>Format: Move ACTION E to previous page. 3.7.1 ACTIONS (continued}
CONDITION R8QUIRED ACTION COMPLETION TIME E. Required Action and .1 -------NOTE-------- a'ssociated Completion LCO 3.0.4.a is not Time of Condition A, C, applicable when
. c::,r D not met
- entering MODE 3 .
Be in MODE 3. 12 hours F Both SSW subsystems F'. 1 12 hours inoperable. OR F.2 36 Hours Two IJHS cooling towers with one or rnore cooling tower fans inoperable. OR UHS basin inoperable foi reasons oth~r than Condition c. SURVEILLANCE REQUIREMENTS SURVEILLANCE FR8QUENCY SR 3.7.1.1 Verify the water level of each UHS basin .j:s i!4 h.¢>ui~f.fi
~ 7.2~ ft.
SR 3.7.1,2 Operate each SSW cooling tower fan for 31 da.~s *.* .......,......,........,....,.
~ 1!:>*minutes.
{¢qnt+/-n4e:~i)'
- In accordance With
- the Surveillance Frequency Control Rrogrcll)l GRAND GULF' 3. 7-3 Amendment No. ~ , *. ~
Page 112 of 173
*: <;Administrative: Reformatted page in accordance with ISTS Writer's Guide>
I* *1 SSW System.and UHS
. 3. 7 .1 SURVEILLANCE REQUIREMENTS continued)
SURVEILLANCE FREQUENCY
~. *- *. *. ** SR 3*. 7."1 . 3
- Verify each required SSW subsystem manuc:1,{ !\ ..
- 31 #a~~.iiE_....~....................
.. power aper ated . and automatic va Ive i n th~:,
*-. . . flow.path servicing safety related systems or components, that l's n(?t locked, sealijtj\
or otherwise secured in position. is in the correct position .
. .":*. . . : ~ 1 0
.= 0 ~ I*:
- I Verify each SSW subsystem actuates on an, 0
SR 3.7.."1 .4 actual or simu,ated initiation signal. tn,accordancewith.
,*' 'I * .,:
~ . : ** t~e Surveillance . Frequency Control .
- Program
- T ,'
. GRAND GULF 3.7-4 Amendment No. ~. - ~
Page 113 of 173
<Administrative: Reformatted page in a'ccordance with ISTS Writer's Guide>
.. HPCS SW$
.. 3.7.2 3.7 PLANT SYSTEMS
,3. 7 .2 High Pressu~e Core Spray (HPCS) Service Water System (SWS)
. . .* **>'_* . . LCO . 3.. 7 . 2 The HPCS ~ws shal I be OPERABLE, 0
~
1 I ,, 0 : I MODES 1, 2. and 3.
*ACTIONS
. .*
- CONptTION REOUiRED ACTION COMPLETION TIME
. . .' ',* *': ..* ,* .. --._..;....---------1----------------+--------
~ *'. ..
' ,: . A. HPCS SWS inoperable. A.1 Declare HPCS System Immediately inoperable.
.. SURVE l LLANCE REQU I REMENTS SURVEILLANCE FREQUENCY
.SR 3 .7 .2 .1 . Verify-each required HPCS SWS manual, power operated. and automatic va Ive in the f I ow*
path servicing safety re I ated systems o~ *
'> *:..
- components, that is not locked. sealed, ¢r oth~rwise secured in position, is in the
- correct position.
SR 3.7.2.2 Verify the HPCS SWS actuates on an actual or simulated initiation signal.
*~ . lhaccordarice with i the Surveillance
'*II
- F'requency Control
- program
- GRAND GULF 3.7-5 Amendment No. 4-20, t~.1*;
Page 114 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
CRFA System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACT ION COMPLETION TIME C. Required Action and C.1 -------NOTE------- associated Co~pletion LCO 3.0,4.a is not Time of Condition A or applicable when B not met in MOJE 1, entering MODE 3. or 2. Be in MODE 3. 12 hours D. Required Act ion and D.l ~lace OPERABLE CRFA Immediate~y associated Completion subsystem in Time of Condition A isolation mode. not met during OPDRVs. OR D.2 Initiate action to Irrunediately suspend OPDRVs. Format: Move ACTIONS E and F from following page. GRAND GULF 3.7-7 Amendment No. 14§, l.lh **~ Page 115 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
CRF.i'\ Syst~m ..----~;Format: Move ACTIONS E and F to previous page. 3.7.3
- Afrr:rONs . Ttontlnue*ctY
- CONDI'l'lON REQUIRED ACTION COMPLETION TlME E. ;'.r:,;.fo CRFA subsystems E.. l -------NOTE-------
).inoperable in MODE 1, LCO 3.0.4.a is not
- 2\; or 3 for roasons applicable ...,hen b£her than Condition entering MODE 3.
';B~
Be in MODE .. 12 hours
*t; Two CRFA subsystems F. 1 -------NOT~------- Irr.mediately
.d.:hoperable during LCO 3.0.3 does not
- oF?DRVs. apply.
lnitidte action to
* :'()ne or moTe CRFA susperid Ol?DRVs.
*.. ~.llbsystems inoperable due to inoperable CRE
*~:oundary during iOPDRVs.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUi::NCY
*~:*...
SR 3.7.3.1 Operate each CR.Fl\ subsystem for~ 15 *,:3,t da.'.f's *~ *-~ continuous minutes. :: ' : ' ~: ~ ' SR
- 3. 7. 3. 2 Perform required CRFA filter tescing .i'h *.ln ac9ot:da~ce,
- accordance with the Ventilation Filter' '.w~th-.1:1\re VFT:~
Testing Program (VF'T!?>. SR 3.7.3.3 Verify each CRFA subsystem actuates 6f:t a11 ' 2l. Yf!Qrti:fr~, ::'~:." .. actual or simulated initiation signat~ SR 3.7.3.4 Perform re~ulred CRE unfiltered air . Trt a.cc:;qtdc;frtc.e,*. inleakage tescing in accordanc~ with ~fh~ *,-,+/-th. the * ; Control Room Envelope Habitability :'G9~ftbl it>c;,m Program. :tnvetope: *:
.:;~;~tj:tilitY : : ******' ...... ,..,
In act:ordahcewith the Surveillance Frequency ,._ 1 __ Qofltrpl .P~og~am. GRAND GULF 3.7-8 Page 116 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Control Room AC System 3.7.4
* *
- ACT I ONS *c cont i nued)
CONOlTION ~EQUIRED ACTlON COMPLETION TIME p
- I :
- II
.* E. Required Action and E.1 Initiate action to Immediately associated Comp I eti on suspend OPDRVs.
Time or Condition B not met during OPDRVs.
- ~ .-. :
,. 'SURVEILLANCE.REQUIREMENTS SURVE I LL ANCE FREQUENCY
*. ..
- SR .3 . 7 . 4 . 1 Ver i fy each contra l room AC subsystem h_as* * -:.zA.'.;lflehthy'"llllli::~'.*..-.....-. ~i;:
the capabi I ity to remove the assumed heat load. . .
* * *,~_.-... :-.. _, ** *** *** - *** , .. -. ,< * ', :
- In accordance with
- the Surveillance .*. 4 1 Frequency Control program .. i:*.
*.. * ...: * .. GRAND GULF ~ 3. 7-ll Amendment No. '%4-6-. *1:97,
- *: ... - Page 117 of 173
,! I
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Main Condenser Offgas 3.7.5 ~ SURVEILLANCE REQUIREMENTS
*. SURVEILLANCE FREQUENCY SR 3.7.5 .. l Verify the gross gamma activity rate of the Once within noble gases is~ 380 mCi/second after decay 4 hours after a of 30 minutes. ~ 50% increase in the nominal steady state fission gas release rate after factoring out increases due to changes in THERMAL POWER level SR 3.7.5.2 -----"---~---------NOTE-~----~-------------
Not. required to be perfonned until 31 days after any SJAE in operation. Verify the gross gamma activity rate of t~~: noble gases is :S 380 mCi/second after dec:aj:*
~!'-~,~'.:-Eii. . . . . . . . .- . ,
of 30 minutes. * ** \ 0 GRAND GULF 3.7-]3 Amendment No. *]if+ Page 118 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
~ ,
Fuel Pool Water Level 3.7.6 ~ 3.7 PLANT SYSTEMS 3.7.6 Fuel Pool Water Level LCD 3.7.6 The fuel pool water level shall be::?:: 23 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool and upper containment fuel storage pool racks. APPLICABILITY: During movement of irradiated fuel assemblies in the associated fuel storage pool. ACTIONS CONDITION REQUIRED ACTION COMP LETIDN TIME A. Fuel pool water level A.. l --------NOTE--------- not within limit. LCD 3.0.3 is not applicable. \ . Suspend movement of Immediately v irradiated fuel assemblies in the associated fuel storage pool(s). SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the fuel pool water level is ::?:: 23 *f~ '*i~_:'~~~-,.iiE':.:-***-**--**--~.-..~--.-*f"-':c:,* over the top of irradiated fuel assemblie$: seated in the storage racks.
===========================================:==::=.;=:===:~~;;5~*. J In accordance with .*
the Surveillance , .... F5requency Control ~ program .* _ ..
- GRAND GULF 3.7--14
- Amendment No. lg~:*.
Page 119 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
tl/7 , ~1.11w1r .$Y~ftM9>
.3,:/2.i? *.Ma,:Lo..*. :Tii,tbft i~ Bt.P~S9 :$.y'$t¢rn
- '.l?li:e }il&n ,rt.rtbfne: Bypass' .,sy~f.~m sh'a:l'I }:)¢ *GJ~EM13:J}~ .,~tt,n
. J~W9 ~~in. *t~,µtpJJt¢ ;~'YP~*iS~ \iJn.'.~c;i.,.' /., *. . '*'
(:OJ;(** ( ~u~ **rne* :i:01:Ibwtri~i I.$)nJ;t:s ~r~****mi:id~ "iiP.Iil.1Lt¢~b1ef Leo'. J .~\Z ~iMtNlfi.UM ;cA:ttr.:t:CAI.. ~POWER c:AATJt):
*<; ~
~ . *. ;:_';:; : *,
\~:f;f;;!t:!f$~! !p:il;~j~i~~~fk~na 0
Leo .3 .'2 ..:3., *'"L'INEAR H'EAW :G'ENiR~Z\T,tett RATE' .
*, **.*,*.;:* 1
*~~;::~1;1!~:isa! !,:::r)Ziiji£!q!£~~!~~;~,µ,;prfy, 0
tHg:frfl.i:\~ :PQ~i1$R )t iij*~* Rtl?
* :i$fi~: :c:ompJtft~
*vJHv~*-.*.. *.*
. . ; . In accordance with
?*~*
................................ i*'.ifcifmat: M6v; SR 3.7;7.1 and SR 3.7.7.2 to new Page 3.7-16. the Surveillance Frequency Control Program 3 /?~~$'; , Page 120 of 173
<Insert new Page 3.7-16>
Main Turbine Bypass System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify one complete cycle of each main turbine bypass In accordance valve. with the Surveillance Frequency Control Program SR 3.7.7.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.7-16 Amendment No. Page 121 of 173
* <Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Operating 3.8.1 ACTIONS (continued) CONDITION 'REQUIRED ACT! ON COMP LET! ON TI ME H. Three or more required H.l Enter LCD 3.0.3. Immediately AC sources inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR J.8.1.1 Verify correct breaker alignment ijrl~~ indicated power availability for ~i¢h required offsite circuit. SR 3 .8 . 1. 2 - - - - - - - - - * - - - - - - - - NOTES - - - - - - - - - - - - ;;. ~ ;,; f*. . ;,; ~ ~
- 1. Performance of s R 3. 8. 1. 21 sirtT~lfe:s this SR.
- 2. A11 OG starts may be precede{l,'bY a:clfi' engine pre lube period and f oJl:o\iie{t tj'_y
- a warmup period prior to loa~'irtg)~
3* A mod if i e d DG s ta rt i nv o1 v i ng i:dllh 9' and gradual acceleration to synchronous speed may be used fof this: SR as recommended by the manufa:¢:tOr:~r: When modified start procedu r~} )f;e: J1bf used, the ti me. voltage, a nci Jr.*e,qufffqj, tolerances of SR 3.8.1.21 mu,sf*bfr;met> : . ., . -~. )"*: ...*:* , ... '
.. - - - - - - - - - .. - .. - - - - - - - - - - - - - - - - - - - -:-*.0:-- ..~*:~::...,*~*-~-:~1** ---.**.
Verify each DG starts from standby. conditions and achieves steady stiti .. voltage~ 3744 V and~ 4576 V and tf~qUiritY
~ 58.8 Hz ands 61.2 Hz.
- ldonttnu.ed;>,*.
In accordancewiththe
- Survejllance Frequency Control Program .
GRAND GULF J.8-5 Page 122 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------- -------NOTE S-----~----- ~------
- 1. OG loadings may include gradual loadfng as recommended by the manufacturer .
- 2. Momentary transients outside the load range do not invalidate this test.
- 3. This Su rv e tl la nee shall be conducted on only one DG at a time.
- 4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.21.
Verify each DG operates for ~-~,:f5Q';mthJ}tis\ at a load ~ 5450 kW and ~ 5740- kW :foir. OG-11 and DG 12, and ~ 3300 kW fot 'o;G- l:9\~ \" SR 3.8.l.4. Verify each DG day tank cont~.+ti's -~-:2':2l)* :~Hrl of fuel oil. SR 3.8.1.5 Check for and remove accumul}tet.~ta.'tef- JJi~Jn each day tank. SR 3.8.1.6 Verify the fuel oil transfef :~y{t~.M, operates to automati cal 1y tfarj{f~r ,*rMJ ,,'o:cjil from the storage tank to th¢- q~J,ta.ni~. SR 3.8.1.7 Verify the load shedding antj* s~,crU'i;Qp]ng-
- panels respond-with in desi~n ¢:rft~r{~i;.'
_.lh accordai1Ge with the SurV~illan:ce.; (, Frequency Control Program . . * * * ?: \. *.... *. GRAND GULF 3. 8-6 -* . .. 1A.1T1e:ridJJie'nt:*~9';, T~f~. :~,;:- Page 123 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>*
AC Source s-Opera ting
- 3. 8.1
*SURVEILLANCE *REQUtREMENTS continu ed SURVEILLANCE FREQUENCY I.;.
SR 3.8.1 .8* -------- -------- -NOTE ---- ------- ------- --- This Survei llance shall not be perrormed in MODE 1 and 2. However, credit may be taken for unpJanned events that satisfy this SR. Verify manual transfe r of unit power suppJM
*from .the norma I o-ffs i te c i rcu it to requ i red
. .,, . alterna te offsitc circui t .
SR 3.8.J.9 *------- ----.--- -NOTE S------ .------- _--- ...:: .. ' 1 . . Credjt may be taken r0r u~planned events that satisfy thrs SR.
":'*
- I
. . . . 2. if* p~rformed with the DG synchro niz~d with ~ffs i te power. i t sha I I be **
perform ed at a power factor ~ 0.9 for QG 11 and DG 13 and ~ O. 89 ror DG 12. However . *i f gr id cond it i ans do not permit. the power factor I i mIt is oat, require d to be met. Under this conditi on the power factor shal I be maintai ned as close to. the I imit as practic able. Verify ~ach DG rejects a Ioad greater than ~- :JnQfltlj~*:,iE-.........--1 or equal to its associa ted single largest . post acciden t load and engine speed is maintai ned less than nominal plus 75% of the differe nce between nominal speed and
* * .... I * ~
- the ovcrspe ed setpoin t or 15% above nominal. whichev er is lower.
*:(q9)itJrnJe~)
- In* accordance with
- the Surveillance Frequency Control
. Program 3.8-7 Amendment No. 469, ****39:t,'
Page 124 of 173
. . . <Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR. 3.8.1.10 *------------------NOT E------- ------------
- 1. Cred i t may be taken for unp1l anned events that satisfy thi~ SR. *
- 2. If per-formed with the DG 5ynchr*oni zed with offsite power, it shall be perfor~ed at a power factor 5 0.9 for DG l1 and DG 13 .1 0.89 for DG 12. However, if grid conditions do not permit. the power factor I i mi. t is not requ i red to be met. Under this condition the power factor shal I be maintained as close to the I iml t as practicab I e.
- Verify each DG does not trip and vo I tage l's: ****.+?****~***.......HH-l'ffi+'l"'"i ........................
ma i nta i ned s 5000 V dur i ng and fo t I ow i ng :a.
- load rejection of a toad~ 5450 kW and
.s 5740 kW for DG 11 and OG 12 and ~ 3300' 'kV{
for DG 13 ..
~ : .. .. ..
GRAND GULF 3.a .. a Amendment No. -1'69, *.**;l~Y:~, Page 125 of 173
... :. \ . <Admini~trativ.e: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Ope rating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3. 8 ..1. 11 - - - - - - . - * - - - - - - - - - -NOTES- - - - - - - - - - - - - - - - - - -
- 1. AI I -DG starts may be preceded by an
*-.: *: engine prelube period.
- 2. This Survei I lance shal I not be performed in MQDE 1, *2. or 3 (Not
'* ... ,,:.,
- Applicable to DG i3). However.\ credit
*maybe tak~n for unplanned events that
.. *
- sati.sFy this SR .
. . ~-- .* ..
Verify on an actual or simulated .toss oF ofrsite power signal:.
. ,-. a. De~energ\i zat ion of emergency buses;
- b. Load shedd i ng 'From emergency buses f9f- ,
Divisions 1 and 2; and
- c. OG auto-starts rrom standby condition*
and:*
- 1. energizes permanently connected loads ins 10 seconds.
- . ,* .. *. :** 2. energizes auto-connec ted shutdown*"
loads, 3: maintains steady state voltage
~ 3744'V ands 4576 v,
- 4. ma i nta i ns steady state frequency:;
~ 58.8 Hz and$ 61.2 Hz. and
- 5. supp I i es permanent*! y connected anrJ auto:-connected shutdown loads for
~ _5 minutes.
lri accordance with the Surveillance
. . .. . . .. Frequency Control
*** , * * *'*r
. -* Pr9gr~rn .
GRAND GULF 3.8-9 Page 126 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Source s-Opera ting 3 .8.1 SURVEILLANCE REQUIREMENTS continu ed
. SURVEILLANCE FREQUENCY '*: I * .-.,.
- SR . 3 *. 8 . 1,. 1 2 . --- . --.----- ------- NQTE S------ ------- ------
- o,
- 1. All *DG starts may be preceded by an engine .prelub e period.
* ,;,* I
*II r
- i. This Surveit lance shal I not be p~rformed in MODE 1,or 2 (Not Applic able to DG 13). However, credit may.be taken for unplanned events that satisfy this SR.
Verify on an actua I or s i mu I ated Emergency:i :~4 .mgr:itf::i$::;*.....................-*'., ij'* Core Cooling System (ECCS) initiat ion ** signal each DG aut,o-s tarts from standby conditi on and: a;
- In ..s 10 seconds after auto-s tart and_**
during tests, achieve voltage
~ 3744 V and frequen cy~ 58.8 Hz;
- b. .AchJeves steady state voltage ~ 3744<((
ands 4576 V and freque ncy~ 58.8 Ht *
*and s 61. 2 Hz;*
- c. Operate s for~ 5 minutes; and
- d. Emergency loads are auto-co nnected tq*
the offsite power system. In accordance with * *
.* the Sutveillance
*.* F}requericy Control:
. Rrogr~m., ...
. G~ANO GULF~-
- 3.8-10 Amendment. No. -t55 ,. ' /1 f37'f Page 127 of 173
<Administrative: Reformatted page in accord~nce with_ lSTS Writer's Guide>
AC Sources - Operating. 3.8.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.8.1.13 *-----..--------"'~ NOl'E---------w****w*---- Credit may be takl!n for unplanned events that satisfy this SR.- Verify each DG's.non-critical automatic tr,ps are bypassed on a11 actual or s1mulatcd ECCS initiation signal. GRAND GULF 3.8-1 l Page 128 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-O perating
- 3. 8.1
./
-SURVEILLANCE REQUIREMENTS continued
- I ~ I *' ~ I : 01 I '
- SURVEILLANCE FREQUENCY SR 3. 8. 1.: 14 - - - - - .- - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - - -
- 1. Momen~ary transient s outside the load
*(
and power factor ranges do not tnvalidat e this test.
- 2. Credit may be .taken for unplanned
.* .... events that satisry this SR .
- 3. lf performed with the DG synchroni zed with orfsite power, it shal J be
- perrormed at a* power ractor ~ 0.9 for.
DG 11 ,;md
- DG 13 and .s O. 89 for DG 12 .
However. if grid condition s do not per.mi t, the power factor I i mi't is not required to be met. Under this I ',,
- o : : *,~ :
condition the power factor shall be I ~ ::
- maintaine d as close to the limit as practicab le.
verify each DG operates for~ 24 hours:
- a. For DG 11 and DG 12 loaded~ 5450 kW and~ 5740 kW; and
. b: For DG 13:
- 1. For~ 2 hours loaded~ 3630 kW.
and*
- 2. For the rema1n1ng hours of the
*test loaded~ 3300 kW.
; I* ',',::,,*,': .
'(cbntihued) lo accordance with * **
. the Surveillance Frequency Control : **
. Program 11
.*. .-* . . GRAND "GULF 3.8-12 Amendment No. +69. ~ -
Page 129 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Ope rating
..... ,.. .* 3 .8.1 SURVEILLANCE.REQUfREMENTS continued
...-- SURVEILLANCE FREQUENCY
-SR 3 . 8. 1 . 15 ------------- -----NOTE S----------- --------
- 1. This Survei I lance shaf I be performed within 5 minutes of shutting down the DG.after-th e DG has operated 2:: 1 hour
_or unti I ope(ating temperature s stab i I. i zed I oaded 2: 5450 kW and
~ 5740 kW for DG 11 and DG 12. and 2::*. 3300 kW for DG 13.
. Momentary transjents outside of the
*'*', I*
. 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~ 3744 V ab~
frequency~ 58.8 Hz; and *
- b. steady state voltage~ 3744 V and~
4576 v and frequency 2:: 58.8 Hz ands 61.2 Hz..
- t~6nt.J'ririetf) .
111 accb'rdancefWith the $urveillance
- - ~- -* ~requency Control
- Program **
1.. ,
.**~ * .. ,! .*. ; GRAND GULF 3.8-13 Amendment No. ~ , *T~l';
Page 130 .of 173
<Adminjst.rative: Reformatted page in accordance with ISTS Writer's Guide> .
.* . . ~ ,: : . -- AC Sources-Operating 1 I I 00 3 .8.1 SURVEILLANCE REQUJREMENTS continued SURVEILLANCE FREQUENCY SR 3 .. 8.1.16 -------------------NOTE---------- . . ------ --- This Sur-veil lance shat I not be perrormed in MODE 1, 2t or 3 (Not Applicable to DG 13).
- .However, credit may be taken for unplanned events that satisfy this SR.
Verity each DG:
- I "*'
I *I* *
- a. Synchronizes with ofrs i te power source- .
wh i I e I oaded with emergency I oads up_brj .. a s i mu I ated res to ration of offs i te * * *
~ - . power;
- b. Transfers toads to orfsite power source; and
~.
- c. Returns to ready-to-toad operation.
* - *.' Jc901:J)1t1~c1J
. In accordance with he Surveillance
_f:'.requency Control
- P.rogram GRAND 'GULF 3.8-13a Amendment No . %5-, 49#"'.
Page 131 of_ 173
. :" ~Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Operating .' 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY
-SR 3 . 8 . l. l7 --------*----------NOTE--------------------
I * '** o* I*
*Gredit n:,ay be taken for unplanned events that satisfy this SR.
* * .,.:* ', ~ "* L : * * ," ..
* : :* : **I? .~ * :* * * *
*. *. -~- *,,; .
Ver i fy, with a DG operat i ng i n test mode * : ~: fflDtitffi'&;~ ~............. and connected to its bus. an actual or ... 1. * -* ** * * *
- simu.lated ECCS initiation signal overrjd$$**
the.test mode by; *
. . .* . ~ .: : -.
- a. Returning DG to* ready-to-load operation; and
* '"p
- 0 ,::*
- I
- b. Automat i ca I Iy energ i z i ng the eme rger1qy*
foads from offsite power.
- SR 3 _- 8 . 1 : 18 . -----* ------------NOTE------ ----------- >.......... : *
- This Surve i I Iance sha I I not be performec.1 MODE 1 . 2 . or 3 . How~ver. c red i t may be *
- taken for unplanned events that satisfy
,* this SR.
I ,*.** .:, *
. ~ .... : *-,"**
.-Verify interval between each sequenced 10:~d*
block is within+/- 10% of design interval
- for each automatic load sequencer.
~ * !,
-GRAND GULF 3.8-14 Amendment No. 1-5-3-, ,:'l!;>~T Page 132 of 173
<Administr~tive: Reform.atted page in accordance with ISTS Writer's. Guide>
AC Sources-Operating 3.8. l .SURVEILLANCE RE UIREMENTS continued)
~URVEILLANCE. FREQUENCY SR 3.8.1.19 ----------------NOTES---~---------------
- 1. All DO starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not be performed in MODE l 2,1 or 3 (Not Applicable to DO 13). However, credit may be taken for unplanned events that satisfy this SR.
Verify, on an actual or simulated loss of offsite power signafJrj:: conjunction with an actual or simulated F:CCS initiation sigtj~lz
- a. De-energization of emergency buses;
.b. _Load shedding from emergency buses for Divisions f~nd .
2;and
- c. DG auto-sta.rts from standby condition and:
/
- l. energizes pcnnanent1y connected Joads in
~ 1Oseconds,
- 2. energizes auto-connected emergency loads,
- 3. achieves steady state voltage~ 3744 V and
- 5 4S76 V~
- 4. achieves steady state frequency ~ S8.8 Hz and
~ 6 l.2 Hz. and
.5. supplies permanently connected and auto-conne~t~4: '..
emergency loads for::: 5 minutes. . ** GRAND GULF 3.8-)5 Amendment No._ m; J.9,?; Page 133 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3. 8 .1. 20 . ---------.---------NOTE--------------- -- --- All DG starts may be preceded by ~n engine prelube period. Verify, when started simultaneously froof standby condition, each DG achieves: *-
- a. in ~ 10 seconds, voltage ~ 3744 V .an*d frequency~ 58.8 Hz; and -
- b. steady state voltage~ 3744 V and.
- S 4 576 V and frequency ~ 58. 8 Hz aijd *,
S 61.2 Hz. SR 3. 8.1. 21 -------------------NOTE--------------- .: -~* .,.;. ' A11 DG starts may be preceded by an engJh~: pre 1ube period and fo 11 owed by a warmup, -*
- period prior to loading.
Verify each DG starts from standby conditions and achieves:
- a. in ~ 10 seconds, voltage ~ 3744 V arf~>*
frequency~ 58.8 Hz; and *
- b. steady state voltage~ 3744 V and
.s 4 s 76 V and frequency =! 58. 8 Hz a:11# -
~ 61. 2 Hz.
GRAND GULF ~.S-16 Amendment No. ~t'.1 182,,
. _** ext.page; 1s.: 3.8"'.'.
Page 134 of 173
u Page 135 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Diesel Fuel Oil, Lube Oil, 3nd Starting Air 3 .. 8.3 SURVEILLANCE REQUIREMENTS SURVEILLANC:'. FREQUENCY SR 3 .. 8.3.1 Verify each fuel oi 1 storage tank contai OS*;,: :,~;ar: ~~Ms;:'~---.. . . . ~
- a. ~ 68t744 gal of fuel for DGs 11 a11d 12; ar.d
- b. ~ 44,616 gal of fuel for DG 13.
~erify lube oil inventory is:
- a. i 410 g~l for OGs 11 and 12: and
- b. ~ 202 gal for DG 13.
*
- R 3.8.3.3 *Verify fuel oil properties of new and :l(n ::a:¢;c9.Jz.9 ~.nPt .:
.stored fuel oil are tested in accordance
- with ,,the. Diesel with, and maintained within the limits ot; tuif *ott ** : **.
- the Dieiel Fuel Oil Testing Program. *t;~t1*.ri~***.*trq:gr.~nt*.*
SR 3.8 .. 3.4 Verify each required DG air start receiv~f pressure is:
~. ~ 160 psig for OGs !land 12; end
- b. ~ 175 psig for OG 13.
SR 3.8.3.5 Check for and r~~ove accumulat~d water each fuel oil storage tank. \ v GRAND GULF 3.8-24 i':l~~~ p~~~ IS ~-~~.2~ **. . : ......[ ....
- ........._*..,;*1'"'.:~; .
Page 136 of 173
u
**TEXt DELE1'EO
- ARlend.,nE!nt N<>*!".12.'$;.1:4. *
. *.JQl{JJ): 20:lO Page 137 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
DC Sources-Operating 3.8.4 ACTIONS (continued} CONDITION REQUIRED ACTION COMPLF,TION TIME D. Required Action and D.l ------~*--NOTE ----- as5ociated Completion LCO J.0.4.a is not Time for Division 1 or a.pplicable when 2 DC electrical power entecing MODE 3. subsystem for condition A, B, or C not me't. Be in MODE 3_ 12 hours E: Division 3 DC E. l Declare High Pressure Irnm.~diately electrica.l power Core Spray System subsystem inoperab1c inoperable. for reasons other than Condition A. F. Required ACLion and Be in 1./JCDE 3 . 12 hoers
-f***.
associdted Completion
~
Time for Division 3 DC ANO eleclrical power . { subsystem for f'. 2 Be in MODE 4. 36 hours Condition A, B or B . not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3 ** 8. 4. l Verity bat t.ery terminal vol Lage is ~ 12f)f on float charge.
'sJ<. 3.8.<1.2 Verify no visible corrosion at batteLy terminals and connectors.
OR Verify batLery connection resistance is 5 1.5 E-4 ohm for inter-cell connectionsj s 1.5 E-4 ohm for inter~rack ~onnections.).
~ 1.5 E-4 ohm for inter-tier connectioni~
and~ 1.5 E-4 ohm for terminal GRAND GULF 3. 9 .... 27 Amendment No. ~ : : ~ Page 138 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
DC Sources Operating 3.8.4 continued SURVEILLANCE FREQUENCY
*: I SR 3.a:4.:3 Verify battery ce I Is, ce f J p Iates. and >:,,,&2"'"4'.-'f'Rf~~~..........~
ra.cks show no vi sua l ind i cation or phys i.¢ij I
' - t damage or abnorma t _deterioration that coLJTd degrade battery perrormance .
.. *_sR 3 ..8. 4.4 Remove Visible corrosion and veri'ry battery ce I J to ce I I and term i na I connect i ans a re" * ',
coated with anti-corrosion material .
- SR 3. 8.4 .5 Veriry battery connection resistance is
. ~*
- s. l.5 E-4 ohm for inter.,.cel l connections~
.s 1 .5 E-4 ohm for inter . . rack connections:
s 1 . 5 E-4 ohm. 'for i riter-t ier connect i omi; . and :S 1 . 5 E-4 ohm for term i na I connect i ohs.- SR *3.8.4.6 Verify *each Division 1 and 2 required battery*charger supplies~ 400 amps at
~ 125 V for~ 10 hours; and the Division* 3 battery charger supplies~ 50 amps at
- I I * *
~ 125 v ror ~ 4 hours.
* I'
,*. : I GRAND GULF 3.8-28 Amendment No. -l-4-r. - ~
' .~ .
Page 139 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SURVElLLANCE FREQUENCY SR 3.8.4.7 ---*---------------NOTES-------------------
- 1. .. SR 3.8.4.8 may be performed in lieu of SR 3.8.4.7 one~
per 60 months.
- 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not appticable to Division 3). However, credit may be taken for unplanned events that satisfy this SR.
Verify battery capacity is adequate to supply, and maintain in. OPERABLE starus the required emergency loads for the desigfr 1 duty cycle when subjected to a battery service test. GRAND GULF 3.8-29 Amendment No. ~~J~7, page 140 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
l DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.4.8 ----***~-*-*-*-*-*-NOTE-----~*--***~------ This Surveillance shall not be performed in MODE l, 2. or 3 (not applicable to Ofv1ston 3). However. credit may be taken for unplanned events that ~atisfy this SR.
+ .
Verify battery capacity is ~ ao:r; of the . iQ<:maAths<-..~--*.................* manufacturer*s rating when subjected to :a performance discharge test. ;AWt 12 .months *when*
.~a}:t~rt s~hbws' :
'de~r'.a~.aJf§~:~*or*
. :Ra$ :r~achef'ast itft~1:fip~#ted
,.*. *capa.c;tW* .< :~Q.9%,-
- :Of . .. ...
fuahµfacturer's*
* .*r.~itn.9** .* .
- u
*Mm,.
. ?4.>;mon'ths wijet)
. b.i'.lt~ry. Q;as*.
- feach~dr:~s:i., :pf':
- t~E!. :eX:pE!cted.*.
'life>w.ith
.* * . *~~_pa:ctty*.*~ Io.o*:t;*
,or ,*.*
'. ill*~nu.fa.cturer'*;s .
. *'ratht_~**.. *
-:-; . -~;.,_ ..' ;- " . . ,,.. *:, '"".. ...
. In accordance with
- 1 the Surveillance -~**
- Frequency Control
. Program GRAND GULF 3.8-30 Amendment No. ~ *. l.39; Page 141 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Battery Cell Parameters 3.8.6 i ACTIONS (continued) \ u CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.l Declare associated Immediately associated Completion battery inoperable. Time of Condition A not met. OR One or more b~tteries with average electrolyte temperature of the representative cells
< 60°F.
OR One or more batteries with one or more battery cell parameters not within. I Table 3.8.6 .. J v Category C limits. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.l Verify battery ce11 parameters meet Table 3.8.6-1 Category A limits. GRANO GULF 3.8-35 Amendment No. +2-e,,l427',
*;.JPN.*:~::;.t7.,.
Page 142 of 173
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Battery Cell Parameters 3.8.6 u SURVEILLANCE REQUIREMENTS (continued) SLIRVEILLANCE FREQUENCY SR 3. 8 . 6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.
..AND,
***on¢~<w,th{n tt**
. hours*'aftJeyf ...
*. battery,.. *.* *
, 9v.~it~.h~tfge**.
- >* .1scr*v* *-*
- SR 3.8.6.3 Verify average electrolyte temperature of.
representative cells is~ so*F.
* ,rratcordaric~*with
- the Surveillance frequency ControL .
Program . * \.. v GRAND GULF 3.8 ... 36 Amendment No *.,:-:f.29:*.;1; Page 143 of 173
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Distribu~ion Systems-Op~rating 3.8.7 ACTIONS lcontinued) CONOI'['ION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 -------NO~E--------
- associaled Completion LCO 3.0.4.a is not
'rime oi Condition A applicdble when or B nol met. ente:rinq MODE *j.
Be in MODE 3. 12 hour-s
- n. One or:: more Division 3 D. l Declare High Pressure Immodiately AC or DC /lectrical Core Spray System power distribution inoperable.
sub5ystems inoperabl~-
~. Two or more divisions E.1 t.:nter LCO 3.0.3. Immediately witn inoperable distribution subsystem5 that result in a loss of function.
SURVEILLANCE REQUIREMENTS SURVl::E,LANCE FREQUENCY SR 3.8.7.l Verify correct breaker alignments and . voltage to requir~d AC and DC electricai\ power distribution subsystems.
- GRAND GULF 3.8-39 Page 144 of 173
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Distribution Systems~Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel . . AND A.2.4 Initiate actions to Immediately restore required AC and DC electrical power distribution subsystems to OPERABLE status. ANO A.2.5 Declare associated Immediately ' required shutdown cooling subsystem(s) inoperable and not in operation. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.l Verify correct breaker alignments and voltage to required AC and DC electrical power distribution 1 subsystems. GRAND GULF *3.8-41 Amendment No. 129: Page 145 of 173
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Refueling Equipment Interlocks 3.9.1
~ , SURVEILLANCE REQUIREMENTS . SURVEILLANCE FREQUENCY
. U SR 3.9.l.l Perfonn CHANNEL FUNCTIONAL TEST on each of . ;(t':'~~~~(.*i~>.-*;'."-*:**.;*--... the following required refueling equipment{. *;
~ .... interlock inputs: . * ** *
- a. All-rods-in,
- b. _Refuel pl atfonn position, and
- c. Refuel platfonn main hoist, fuel loaded.
u
\ I GRANO GULF 3.9-la Amendment No. ~ , i.;{18,\
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Refuel Position One-Rod-Out Interlock. 3.9.2 ~ 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE. APPLICABILITY: MODE 5 with the reactor*mode switch in the refuel position and any control rod withdrawn. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one- A.l Suspend control rod Immediately rod~out interlock withdrawal. inoperable. AND A.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verffy reactor mode switch 1ocked in refuel position. *
- GRAND GULF 3.9-2 Page 147 of 173
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Refuel Position One-Rod-Out Interlock 3.9.2 u SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.9.2 .. 2 ----------------*-~NOTE------------~~~----- Not required to be performed until 1*hour after any control rod is withdrawn. Perform CHANNEL FUNCTIONAL TEST.
** 111 accordarice with*
the'Surveillance
'7requency Control *
'. Program ..
GRAND GULF 3.9-3 Amendment No. -;l'.291?, Page 148 of 173
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Control Rod Position 3.9.3 ~ 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9 . 3 All control rods shall be fully inse.rted. APPLICABILITY: When loading fuel assemblies into the core. ACTIONS CONDI Tl ON REQUIRED ACTION COMPLETION TIME A. One or more control A.l Suspend loading fuel Immediately ro~s not fully assemblies into the inserted. core. \
~ SURVEILLANCE REQUIREHENTS 1 SURVE llLANCE FREQUENCY SR 3.9.3.l Verify all control rods are fully inserted~<
GRAND GULF 3 .. 9-4 Amendment No. '.,t!Q; Page 149 of 173
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Control Rod OPERABILITY-Refueling 3.9.5 ~ 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY-Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE. APPLICABILITY: MODE 5. ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME A. One or more withdrawn A.l lnit;ate action to Immediately control rods fully insert inoperable4 inoperable withdrawn control rods. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.l * ..... ---- -- -- ----- ---NOTE--.- .. --- --- .. --.. -- -- -- Not required to be performed until 7 days after the control rod is withdrawn. Insert each withdrawn control rod at lea§t* one notch. SR 3.9.5.2 Verify each withdrawn control rod scram accumulator pressure is;: , 1520 psig. \ u GRAND GULF 3.9-7 Amendment No. }ecr, Page 150 of 173
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RPV Water Level--Irradiated Fuel 3.9.6 \~ 3.9. REFUELING OPERAT10NS 3.9.6 Reactor Pressure Vessel (RPV) Water Level~Irradiated Fuel LCO 3.9.6 RPV water level shall be ~22 ft 8 inches above the top of the RPV flange. APPLICABILITY: During movement of irradiated fuel assemblies within the RPV. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.I Suspend movement of Imrnediately within limit. irradiated fuel assemblies within the RPV. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.l Verify RPV water level is 2!: ZZ ft B inches: * *.:24:~1,~~1:.¥:,;*...***-*- -... above the top of the RPV flange. \
\_)
GRAND GULF 3.9-8 Amendment. No. *ile_e\: Page 151 of 173
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RPV Water Level--New Fuel or Control Rods 3.9.7 3.9 /REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel *(RPV) Water Level--New Fuel or Control Rods LCO 3.9.7 RPV water level shall be~ 23 ft above the top of ;rradiated fuel assemblies seated within the RPV. APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV. ACTIONS CONDITION REQUIRED ACTION COM PL ET ION TIME A*. RPV water level not A.I Suspend movement of Immediately within limit. new fuel assemblies and handling of control rods within the RPV.
- SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.l Verify RPV water 1eve 1 is ~ 23 ft above the:
top of irradiated fuel assemblies seated'** within the RPV. \.
\.J GRAND GULF 3.9-9 Amendment No. ra~e.~.;;:
Page 152 of 173
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RHR-High Waler Level 3.9.8 ACTIONS CONDITION RF.QUIRED ACTlON COMPLETION TIME B. (continued) B.3 Initiate a::tion to Immediately restore one sLandbj* gas treatment subsystem to OPERABLE stalt.s. AND B.4 Iniliale aclian Lo Inunediately restore isolation capabLity ln each req1..1 red secondary containment. penetration floYoJ path not isolated.
- c. No decay heat removal C.1 Verity reaclor 1 hour trom subsyslem ln coolant cir::ulation discovery of no operation. by an al tern.ate reactor coolant method. circulation AND Once per 12 hours Lhereafter AND C.2 Monitor reactor Once per hour coolant Lemperalure.
SORVEII.LANCE REQUIREMENTS SURVEILLANCE FREQUENC't SR 3.9.B.l Verify one decay heat operalin.g. SJt 3.9.H.2 Verify required RHH shutdow& ccic,J.;1,i1~1t s*.1bsystem locations suscept{}?-ie:>tci .9..:a'S'.i, *: accumulation are suff icient:ly fil:L~J:f \'.Ji'tf! water. ( .3
- 9- J J lh accordancewitn *
- the Surveillance Frequency Control Page 153 of 173
- program
<Insert new Page 3.9-11a>
RHR - High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS continued) SURVEILLANCE FREQUENCY /,SR 3.9.8.2 Verify required RHR shutdown cooling subsystem In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program GRAND GULF 3.9-11 a Amendment No. Page 154 of 173
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3 *9 REFUEL ING OPERATJ ONS RH~\,;! "J ;}\il:°t'¢1', ,~~,,,: 3.9.9 Residual Heat Removal CRHR)- Low Water Level LCO 3.9.9 Two decay heat removal subsystems sha11 be OPERABLE, and one decay heat removal subsystem shall be in operation.
*--~--------------~****~-*~~NOTE-----------------------*****
The required operating decay heat removal subsystem may not :'b;;, be in operation for up to 2 hours per 8 hour period. n****
-*~*-*--*-*----------------------*----*--*------**-~**~-~*--
APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel CRPV) and the water level< 22 ft 8 inches above the top of the RPV flange. ACTIONS
--------------------------------*------**NOTE~-----------*--------------*---- *se~arate Condition entry is allowed for each decay heat removal subsystem. \ ~---w-----*--*-*****-*******************-************-*******-*********-*-***
u . CONDITION REQUIRED ACTION COMPLETION TI ME
*A. One or two required A.l Vefify an alternate 1 hour decay heat removal method of *decay heat subsystems inoperable. removal is available*
for each inoperable required decay heat Once per removal subsystem. 24 hours thereafter Cconti nued) I GRAND GULF 3.9-12 Amendment No. ~t.Jk2>:*:,
;. -~;_-e.e:: 2889:-)
Page 155 of 173
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RHR - Lew Water Level 3.9.9 SURVEILLANCE REQUlREMENTS SURVE1LLANCE FREOU£NCY SR 3. 9. 9.::. Verify one decay heat removal subsystem~~ operating. SR 3.9.9.2 Verify RHR shutdown cooling subsystem locations susceptible to gas accumulatio& are suffici~ntly filled with water. GRANO GULF 3. 9-14 Amendment ~o. ~ , zf9g,; Page 156 of 173
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Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor 1 hour mode switch in the shutdown position .
.QB A.3.2 --~-----NOTE---------
Only applicable in MODE 5. Place the reactor
- 1 hour mode switch in)the refuel position.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.I Verify all control .rods are fully insert~*q\ in core cells containing one or more fuel'. assemblies.
- SR 3.10.2.2 Verify no CORE ALTERATIONS are in progre~'s\.
'-\._/ GRAND GULF 3.10-5 Amendment No. {3.~;;~, Page 157 of 173
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Single Control Rod Withdrawal~Hot Shutdown
. 3.10.3
~ SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.l Perform the applicable SRs for the required According to LCOs. the applicable SRs SR 3.10.3.2 ~---~~~**-**--**---NOTE--*-**-*--*-~--~--~- Not required to be met if SR 3.10.3.l is satisfied for LCO 3.10.3.d.l requirements. Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. SR 3.10.3.3 Verify all control rods, other than the control rod being withdrawn, are fully inserted. In accordance with the Surveillance f:requency Cqr,trol program GRAND GULF 3.10-8 Amendment No. ?~:,, Page 158 of 173
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Single Control Rod Withdrawal--Cold Shutdown 3.10.4 u ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION HME B. *one or more of the B.l Suspend withdrawal of Immediately
- above requirements not the control rod and met with the affected removal of associated control rod not CRD.
insertable. AND B.2.1 Initiate action to .Immediately fully insert all control rods. 8.2.2 Initiate action to Immediately satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.l Perform the applicable SRs for the required According to LCOs. applicable SRs SR 3.10.4.2 -------------*-*~-*NOTE-~~---~*-*-**~-~-~~~ Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.l requirements. Verify all control rods, oth~f:th~ft*.~"be:*: *.: . :g:~:-:b,bur:s.;;.>~;,..__-......-.... control rod being withdra~, Jn, a:, fj;y:~---by;. five array centered on the ~~<>rttr:Ql .r.og> * '. being withdrawn, are di sar111ed:,",
- GRAND GULF 3.10*11 Page 159 of 173
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Single Control Rod Withdrawal--Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.10.4-3 Verify all control rods, other than the control rod being withdrawn, are fully inserted . SR 3.10 .4. 4 ---*- .. ~-**- __ .............. NOTE-**--....... -- - ...... ------~_::..: Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.l requirements~ Verify*a control rod withdrawal block ;s inserted. GRAND GULF 3.10-12 Amendment No.*. :-12:(1, Page 160 of 173
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Single CRD Remova1~Refue1ing
- 3. JO. 5
\_) _AC_T_IO_N_S______........;..______________________________________________ CONDITION REQUIRED ACTION COMPLETION TIME A. {continued) A.2.1 Initiate action to Immediately fully insert. all control rods. OR A.2.2 Initiate action to Immediately satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all controls rods, other than the control rod withdrawn for the removal of the associated .CRO, are fully inserted. SR 3.10.5.2 Verify all control rods, other than the. control rod withdrawn for the removal of" the associated CRD, in a five by five a.rtay ; centered on the control rod withdrawn for*. the removal of the associated CRD, are disarmed. SR 3.10.5.3 Verify a. control rod withdrawal block is inserted. GRAND GULF 3.10-14 Amendment No.;~;,;~ Page 161 of 173
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Single CRD Removal--Refueling 3.10.5 u SURVEILLANCE REQUIREMENTS *(continued) SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1..1.1. According to SR 3.1.1.1 SR 3 .10.5. 5 Verify no CORE AlTE_RAT~ONS are in progress:., In accordance with *. he Surveillance Frequency Contr,ol . Program.. * ** \. u GRAND GULF 3.10-15 Amendment No. <la.ff" I Page 162 of 173
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Multiple Control Rod Withdrawal--Refueling 3.10.6 ACTIONS u \. I
~~-------------~--------~-----
CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.l Initiate action to Immediately
/ fully insert all control rods in core cells containing one or more fuel assemblies.
A.3.2 Initiate action to Immediately satisfy the requirements of this LCO .. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6 .. 1 Verify the four fuel assemblies are remo.v~d>
- i i t f . t b - ~ ~ ~ -.............. ;,*.,
from core eel 1s associated with each - *- * - control rod or CRD removed. SR 3.10.6.2 Verify all other control rods in cote,-:ceHs\. containing one or more fuel assembl iEt$*: ~tij - : fully ;nserted. SR 3.10.6.3 --------~~---------NOTE---~~-----~~--~~~~~~~ Only required to be met during fuel 1oading.
--------------~~-*------------------~~~?~~~
Veri f y f ue1 as semb1i es being 1oaded a._rttJti > comp1i ance with an approved spi ra1 rel9:a<:L_ sequence. GRAND GULF 3.J0 .. ]7 Pa~e 163 of 173
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SDM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued} SURVEILLANCE FREQUENCY l SR 3.10.8.2 --~------~~~--~~---NOTE----*----~-~--*~---- Not required to be met if SR 3.10.8.3 satisfied. Perform the MODE 2 applicable SRs for According to LCO 3.3.2.1, Function 1.b of the applicable Table 3 .3.2.1-1. SRs SR 3*.10.8.3 --------- ... - ... -------NOTE---------.. . ---------- Not required to be met if SR 3~10.8.2 satisfied. Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the SDM test by a second licensed operator or other qualified member of the technical staff. SR 3.10.8.4 Verify no other CORE ALTERATIONS are in progress.
. "' *' .. '; ... *. : ... : *.. :.,_.: ;,:,. *" .,, ,, ' ...... *, . ' ,_;,:,; '. -~* .. : ~-:' .. :* . .
,**., ,., ... *.*;<<;**-* \:
fgg,ht-fhu~~l:*:.
- In accordance with* .,
.
- he Surveillance
.* Frequency Control
* ~rogram
'\
\:J GRAND GULF 3.10-21 Amendment No. <fe{}\
Page 164 of 173
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SDM Test--Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.10.8.S . Verify each withdrawn control rod does not Each time the
- go to the withdrawn overtravel position. control rod is withdrawn to 11 full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling
\ __) SR 3.10.B.6 Verify CRD charging water header pressure
~ 1520 psig.
\ v GRAND GULF 3 .. 10-22, Amendment No .. ' ~ Page 165 of 173
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- S4PcPre{Si,c#l\),!l.i>;t '8a~e,llp,,::';l~~ti,
-*. .(SIR;' Jij'.l(~JP_:~-1~(iy .
- i~uppressi6ri'j)601 : :~:~,;2;: ... f;--:*-***.-*..... : _...,
. . - -. . . . . . .----'**:,:..,.*.-::':..,..::,.:_-;_:_.,.,** _-*_,:._:_**_*____: *,_*.*_:_._i_)~_i_
.* . . .. .,-. __:_._._t:!_.*.~-~i_._-_**_'~.~=-_,_-_.*.*_r_*_::_."_e_;;!:_._._-__e_:~e.t_:_._*_a_,_!r~~:_:.~_:_:; **
- _~_~_J~:,l*p_l_:_*~_._u~
'.:.r_._._-_ ,_:_**_._._;_*_--.:_*_.y_f
.':l;~?ppre~.siqp..pppl:;'::z:_"""........._...,........,._
**:i **_, , ..-,.{",.~ ,*;
Page 166 of 173
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Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.5 Component Cyclic or transient Limit This program-provides controls to track the cyclic and transient occurrences identified on UFSAR Table 3.9-35 to ensure that the reactor vessel is maintained within the design limits. _pury~illcmq.e FreguencyContrC>IF>rogra~'.'.---- . . ---.***
.** This program provides controls-for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications
; are performed at intervals sufficient to assure the associated Limiting Conditions '
- or Operation are met.
~- The Surveillance Frequency Control Program shall contain a list of
_Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
- b. Changes to the Frequencies listed in the Surveillance Frequenpy Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.
- c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
(continued) GRANO GULF 5.0-11 Amendment No . .:t-20, 14 2;,:g~t;, *, Page 167 of 173
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with ISTS Writer's Guide> J Programs and Manuals 5.5 5.5 Programs and Manua1s 5.5 .. 8 ExoJosive Gps and Storage Tank Badigactiy]tv Monitoring Program (continued)
- b. A surveillance program to ensure that the quantity of radioactive material contained in any outside temporary tank not including liners for shipping radwaste is !: 10 cu.ries, '~,
excluding trit;um and disso1ved or entrained noble gases. The provisions of SR 3.0.2 and SR 3~0.3 Bre applicab1e to the Explosive Gas and Storage Tank Radioactivity Monitoring Program survei11ante frequencies. 5.5 .. 9 Diesel Fuel OiJ Testing Program A diesel fue1 oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shell include sampling and testing requirements, and acceptance.criteria. a11 in accordance with applicab1e ASTH Standards. The purpose of the program is to esteblish the fo11owing: *
- a. Acceptabi1ity of new fuel oil for use prior to addition to
. ,s.~~-~age .tanks_, /~rid acc,~ptabj) i ty of stored fue 1 oi 1r.:~,i~.t,y ~er{'
,_,,,*(. I ~ :. ;..,;.......~~~~,-~~~*~/*'ib,l' de'~~rrritni.rig:"~~a-t . *.1;he fuel oi 1 has:
*h .':ij> wat$r: .a_hd }'~ ij,itrfrat: c'cin.~~nh wi thin , i mi ts' and er -ld:riematic,,Viscbstty Z'~ .o,r;*-,' ... :' .* ,*, .'. w.;l:thin
* . *...... . limits* for ASTM 2D fuel
. . .h. * :f~tat:":p~;r;;tt;ut~#e:*conq~n-trqftion of the new fue1 is
.Z:*:2 :mg/100 :.~l .* w~:er, itesled -;~ :accordance with ASTM D-2274* 70
*wi:tMn*i,y**d~.t~* *afttfr*_ :a.c1dftl\ln. cjf the new fue1 to the $torage t~n~o;; /~nd * * ** **
ata requ*ency in accordance with the Surveillance Frequency
~9r1tr9I Prpgrc1m_. "r6e* .:pf6,\r.fs110.ij~*:,tf :'s:it_;,ai.0}2: in~:::S:R)*a~o.3 are appl i cab1 e to the Dies~l ~~~1 Oil Testirig Pro~rim testing frequencies.
(continued) GRAND GULF 5.0-14 Page 168 of 173
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-~* Page 1S9 of 173
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.___ ... _... _.-:\Format: Move text from previous page. Programs and Manuals s.s u* Jt:Si . PrClgrams and Manua1( *, . ~* . ., . . *.* * :
. Safety Function Determination Program f SFDP) (.~e"th1~¢~r
.......----~~~*>~<or compensatory actions may be identified to be taken as a result
,of the support system inoperabil ity and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:
- a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected; b.. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;
- c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropr;ately extended as a result of multiple support system inoperabilities; and
- d. Other appropriate limitations and remedial or compensatory actions.
A loss of safety function exists when, assuming no concurrent
- 0. . single cannot failuret a safety function assumed in the accident analysis be performed. For the purpose of this program, a loss of
- safety function may exist when a support system is inoperable, and:
- a. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or
- b. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or
- c. A required system redundant to support system{s) for the supported systems (a) and (b) above is also inoperable.
The SFDP identifies where a 1oss of safety fun ct ion exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. {continued)
\ \J GRAND GULF 5.0-15 Amendment No *. f2:9, Page 170 of 173
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Programs and Manuals 5.5 5.5 Programs and Manuals (cont~nued)
- 5. 5.11 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.
- a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviewsa
- b. Licensees ma~* make changes to Bases without prior NRC approval provid(*d the changes do not require either ,of the following:
A change i~ the TS incorporated in the license: or
- 2. A change to the updated FSAR* or Bases that requires NRC approval pursuant to 10 CFR 50.59.
- c. The Bases Control Program shall contain provisions to.ensure that the Bases are maintained consistent ~ith the UFSAR.
- d. Proposed chang~s that do not meet the criteria of either Specific~tion 5.5.ll~b.l or Specification 5.5.11.b.2 above
.shall be re:vie\'t'ed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to ~he NRC on a frequency consistent with 10 CFR 50. 71 {e} .
5.5.12 10 CFR 50, Appendix ,J, Testing Program This program establi~hes the leakage rate testing program of the containment as requi.red by 10 Cf'R 50. 54 {o) and 10 CFR 50, Appendix J, Opt.ion B, as modified by appro,ted exemptions. This program shall be implemented in accordance with the Safety Evaluation issued b~ the Office of Nuclear Reactor Regulation dated April 26, 1995 (GNR!-95/00087) as modified by the Safety Evaluation issued fl~r Amendment No. 135 to the Operating License, except that the nex1 Type A test performed after the October 19, 2008 Type A test shall be performed no later than the plant restart*after the End of Cycle 22 Refueling Outage. For Type B and Type C local leakage rate testing, this program shall be in accordance with the guidelines contained in NEI 94-01, Revision 3-A, "!ndustry Guideline for Implementing Performance-Based Option of 10 CFR Part S1i: ;,..~pendix J,"' dated July 2012, Consistent with standard scheduling practices for Technical Specitications required surveillan .es, intervals for the recommended surveillance frequency for Type A testing may be extended by up to 25 percent of the test interva~, not to exceed 15 months. The calculated peak containment internal pressure for the design basis loss of
.coolant accident, P1, is :2.1 psig.
'J<:?ntmuedld < . . *.* <~ .*.
- Amendm~nt N'o~:~,,4@4:; ~.*.~~ , ~ . ~
GR:~gr~~tChange to single line} 5
- O-l 6 Page 171 of 173
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Programs and Manuals S.5
- 5. 5 Progtams and Manuals (continued)
S.S.13 control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE control Room Fresh Air (CRFA) system, CRE occupants can control the reactor safely under
.r'Pt'!'~l c911cH.~.ipns an<tmc1~11t:a.in __ i"1: jJ1, a ~.af, son~i!i~m fol}owing a ra.dJo,l9s1*ca] :*,ev!e"t~.* :*,hazard9us chemical* rel~ase,, . .*. or, ;~;. smo~e-total effective - :thallen .e~.. :the.: . ref dtin sfiall: ensu'r,iLthat ad~ 'uate tad,fa;i:on>
dose_E}qLJivc1IE}r1t: . *p.*. r._o......*~.,........e *~.*.*i~.-_..:.o. t'J*.*/J.;S...-,'_P_**.r..*.'°.**.v_. . . . . ,.*_.*-;. -.*.* . e.-*.**-.--***.*.*.*.*:t_**C?. . . -,-.*-p*****e*:r*rn_.*-J*:t... ** ...*.a*c*.*.c;.E!s*.*.*.s_*.*._*.**.*-**.*_.~_rf_.>*o. . . c.--..flt*.*. p*...*.*.*-.a... y*.**--.*. .P.*.**_'.*f.*.**.,;:*:t.-**:*. .h.-.-.*-.*.e. '. *.*_:.;:,. c.*:.*._R.*_.*.*.E_.* .-*
* ;;-uncler:o,es,.gn ,-Bi!$JS, Acc,:dent (DJ3M con:d1-t1.on~..:;w1thout ._ rson,nel
- _ _**_"_,.*.*.**.**.c,-
/~s~j.'Y.tns_*pa:rJ:i'9:~i9n,).Epcpo~_ut~s,,:-i'ri.\~~~~~J ~f"':~:t-¢ffi):,:: . _:_: ;\'; .- . . * ;.,*~:',
;li).e.s~.0,E~1:11va1eF1t *(TE~E)>fe>r :the,dµrat1on of.::tne*,ac::c1dent~ The; program shall foclu'de the following elements: . .. . . '
- a. The definition of the CRE and the CRE boundary~
- b. Requirements for maintaining the CRE boundary in its design condit;on including configuration control ana preventive maintenance.
Jt) t.l~t~.17.UJinfng,Iih~ __ :,J.irifi 1ter~d air
, .*. *.*- . _**-*..*..... i -, , _ ....*.*** -.-.*- < .. *.... :*. * . o;:thl:! ,CRE 1 n accordance
*W1/t:h';::-t,t,~-:~i~ti:_rjff m~:fngds.)il~<:J:,a~: :~.b~-.-, Afequenci es specified ; n
'.Sec:tions;:c-;.1-;::and* c.-2, of Regulatory~>;l.197, H[)emons"trating 'Control Room Erivel ope Integrity at Nuclear Power Reactors.,** Revision 0, May 2003 and (ii) assessing CRE habitability at the Frequencies specified in sections c_1
. and c.2 of Regulatory Guide 1.197, Revision O. _
- d. Since the.CRE is at a neutral pressure during isolation mode, the CRE will be maintained, including the following:
l~ Plant maintenance activities such as modifications, rework, and preventive maintenance tasks on components that could affect the CRE shall be controlled under fleet. plant and system specific procedures to ensure that the CRE boundary is not degraded by such activities.
- 2. Testin$ of CRFA system sealin9 areas shall_ be performed following maintenance activities (rework and preventative) and periodically to ensure that the areas of negative pressures do not leak bypassing emergency filtration system components.
- 3. Fire damper inspection procedures that require opening of duct panels and doors shall ensure that upon restoration no leakage path exists.
4'*- The remainder of ducting components such as plenum access doors 1 duct access doors (rectangular and round), flex connections (ventglass, etc.). plugs, and patches wi11 be maintained per paragraph b. .* - *.. * ._ . . .
- J(~ontinued),J~**
GRAND GULF Amendment No, ;<JW ~.* Page 172 of 173
<Administrative: Reformatted page in accordance with ISTS Writer's Guide>
Format: Move 5.5.13.d.4 from previous page. Programs and Manuals r"""'!'!"'~~.......... s.s
- tonthoJ ifoom Envelope }tabitabi 1ity Program (continued)
......................._..,__......,....,......,......,**-'*,.11,tis.'. Ari'ia~~:~:~~m~n'( ~tthe CRE Boundary will be conducted iat a frequency in *.
.. _ _ * .* - ~- :. : The resul t:s of assessing items 1
. h'r9ugtt 4: sliaJ l'.:'be trended and used as part of the
'accordance with the as.s:'~$~m~_n't 9:f' the CRE. boundary as indicated in paragraph
.c-;*.* - .
.Surveillance Frequency Control the :quaiiti'.':t~:dve,Jifoit:s 00 unfiltered air inleakge into the CRE~ * "th¢se:li:mi>ts*j;hall be stated in a manner to allow ero ram dtrect <iO:rnp~ds'orj::fo the unfiltered air inleakage measured by ttfetesfin9described in paragraph c .. The unfiltered air inleakage limit for radiological challenges i:s the inleakage flow rate assumed in the licens;ng basis analyses of OBA consequences . unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assufflptions in the licensing basis . *
- f. The ~rovisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability. de~ermining CRE unfiltered inleakage, and assessing the CRE boundary as required by paragraphs c and d, respectively.
GRAND GULF S.0-16b Amendfflent No. PB-':-, Page 173 of 173
Attachment 4 to GNR0-2018/00013 Revised Technical Specification Pages (162 pages)
Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. In accordance with the Surveillance Frequency Control
,Program SR 3.1.3.2 Deleted SR 3.1.3.3 -------------------------------NOTE--------------------------------
Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RPCS. Insert each withdrawn control rod at least one notch. In accordance with the Surveillance Frequency Control Program SR 3.1.3.4 Verify each control rod scram time from fully In accordance with withdrawn to notch position 13 is s 7 seconds. SR 3.1.4.1, c' SR 3.1.4.2, SR 3.1.4:3, and SR 3.1.4.4 (continued) GRAND GULF 3.1-10 Amendment No. 120, 180, Page 1 of 162
Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS
NOTE-------------------------------------------------------------
Ouring single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.
- SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after
~ 950 psig. each reactor shutdown
~ 120 days SR 3.1.4.2 Verify, for a representative sample, each tested In accordance with control rod scram time is within the limits of the Surveillance Table 3.1.4-1 with reactor steam dome pressure Frequency Control
~ 950 psig. Program SR 3.1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam control rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time (continued)
GRAND GULF 3.1-13 Amendment No. 150, 169, Page 2 of 162
Control Rod Scram Accumulators 3.1.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Declare the associated 1 hour control rod inoperable. D. Required Action and D.1 ------------NOTE------------- associated Completion Not applicable if all Time of Required Action inoperable control rod B.1 or C.1 not met. scram accumulators are associated with fully inserted control rods. Place the reactor mode Immediately switch in the shutdown position. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator pressure In accordance with is~ 1520 psig. the Surveillance Frequency Control Program
/
GRAND GULF 3.1-18 Amendment No. 42-0, Page 3 of 162
Control Rod Pattern 3.1.6 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more 8.1 -------------NOTE-------------- OPERABLE control Affected control rods may rods not in compliance be bypassed in RACS in with BPWS. accordance with SR 3.3.2.1.9 for insertion only. Suspend withdrawal of Immediately control rods.
- AND 8.2 Place the reactor mode 1 hour switch in the shutdown position.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply with In accordance with 8PWS. the Surveillance Frequency Control Program GRAND GULF 3.1-20 Amendment No. 420, Page 4 of 162
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.1.7.1 Verify available volume of sodium pentaborate In accordance with solution is~ 4,200 gallons. the Surveillance Frequency Control Program SR 3.1.7.2 Verify temperature of sodium pentaborate solu_tion is In accordance with
~ 45°F and~ 150°F.
the Surveillance Frequency Control Program SR 3.1.7.3 ---------------------------------NO TE-------------------------------- Sod ium pentaborate concentration (C), in weight percent, is determined by the performance of SR 3.1.7.5. Boron-10 enrichment (E), in atom percent, is determined by the performance of SR 3.1.7.9. Verify SLC System satisfies the following equation: In accordance with (C){E) ~ 420. the Surveillance Frequency Control Program SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.1-22 Amendment No. 120, 190, Page 5 of 162
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify the percent weight of sodium pentaborate in In accordance with solution is ~ 9.5%. the Surveillance Frequency Control Program Once within 24 hours after water or boron is added to solution Once within 24 hours after solution temperature is restored to
~45°F SR 3.1.7.6 Verify each SLC subsystem manual, power operated, In accordance with and automatic valve in the flow path that is not the Surveillance locked, sealed, or otherwise secured in position, is in Frequency Control the correct position, or can be aligned to the correct Program position.
SR 3.1.7.7 Verify each pump develops a flow rate ~ 41.2 gpm at In accordance with a discharge pressure~ 1370 psig. the INSERVICE TESTING PROGRAM SR 3.1.7.8 Verify flow through one SLC subsystem from pump In accordance with into reactor pressure vessel. the Surveillance Frequency Control Program (continued) GRAND GULF 3.1-23 Amendment No. 190, 197, 205, 211, Page 6 of 162
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY
\
SR 3.1.7.9
- Determine Boron-10 enrichment in atom percent (E). Once within 24 hours after boron is added to the solution SR 3.1.7.10 Verify piping between the storage tank and the pump Once within 24 suction is not blocked. hours after solution I temperature is I
restored to
~45°F GRAND GULF 3.1-24 Amendment No.
Next page is 3.1-26 Page 7 of 162
SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 --------------------------------NOTE-------------------------- Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2. Verify each SDV vent and drain valve is open. In accordance with the Surveillance Frequency Control Program SR 3.1.8.2 Cycle each SDVvent and drain valve to the fully In accordance with closed and fully open position. the Surveillance Frequency Control Program SR 3.1.8.3 Verify each SDV vent and drain valve: In accordance with the Surveillance
- a. Closes in s 30 seconds after receipt of an Frequency Control actual or simulated scram signal; and Program
- b. Opens when the actual or simulated scram signal is reset.
GRAND GULF 3.1-27 Amendment No. 120, 197, Page 8 of 162
APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Average Planar Linear Heat Generation Rate (APLHGR)
\
LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR. APPLICABILITY: THERMAL POWER~ 21.8% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to 2 hours limits. within limits. B. Required Action and B.1 Reduce THERMAL 4 hours associated Completion POWER to< 21.8% RTP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal Once within to the limits specified in the COLR. 12 hours after
~ 21.8% RTP In accordance with the Surveillance Frequency Control Program GRAND GULF . 3.2-1 Amendment No. 120, 191, Page 9 of 162
MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Minimum Critical Power Ratio (MCPR) I I LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR. APPLICABILITY: THERMAL POWER 2! 21.8% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to / 2 hours limits within limits. B. Required Action and 8.1 Reduce THERMAL 4 hours associated Completion POWER to< 21.8% RTP. Time not met. SURVEI.LLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal Once within to the limits specified in the COLR. 12 hours after 2!*21.8% RTP In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.2-2 Amendment No. 120, 191, Page 10 of 162
MCPR 3.2.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours after each completion of SR 3.1.4.1 Once within 72 hours after each completion of SR 3.1.4.2 Once within 72 hours after each completion of SR 3.1.4.4 GRAND GULF 3.2-3 Amendment No. Page 11 of 162
LHGR 3.2.3 3.2 POWER OISTRIBUTION LIMITS 3.2.3 Linear Heat Generation Rate (LHGR) LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR. APPLICABILITY: THERMAL POWER~ 21.8% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within A.1 Restore LHGR(s) to 2 hours limits within limits. B. Required Action and 8.1 Reduce THERMAL 4 hours associated Completion POWER to< 21.8% RTP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to Once within the limits specified in the COLR. 12 hours after
~ 21.8% RTP In accordance with the Surveillance Frequency Control Program GRAND GULF 3.2-4 Amendment No. 120, 191, Page 12 of 162
RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS
.----------NOTES-----------------------------------------------------------
- 1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains RPS trip capability.
SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.2 ----------. ------------------NO TE------------------------------ Not required to be performed until 12 hours after THERMAL POWER~ 21.8% RTP. Verify the absolute difference between the average In accordance with power range monitor (APRM) channels and the the Surveillance calculated powers 2% RTP while operating at~ Frequency Control 21.8% RTP. Program SR 3.3.1.1.3 -----------------------------NO TE------------------------------ Not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-3 Amendment No. ~ 494, Page 13 of 162
RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.1.5 Deleted SR 3.3.1.1.6 Deleted SR 3.3.1.1.7 Calibrate the local power range monitors. In accordance with the Surveillance Frequency Control I Program SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.9 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-4 Amendment No. 4e9, 4-7-7, Page 14 of 162
RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.3.1.1.10 ---------------------------NOT ES------------------------------
- 1. Neutron detectors are excluded.
- 2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
- 3. For Function 2.d, APRM recirculation flow transmitters are excluded.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-4a Amendment No. 141, *188, Page 15 of 162
RPS ,Instrumentation 3.3.1.1 .SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.1.11 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.12 ----------------------------NOT ES-----------------------------
- 1. Neutron detectors are excluded.
- 2. For IRMs, not required to be performed when entering MODE 2 from MODE 1 until 12 hours
. after entering MODE 2.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.13 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.14 Verify Turbine Stop Valve Closure, Trip Oil In accordance with Pressure-tow and Turbine Control Valve Fast the Surveillance Closure Trip Oil Pressure - Low Functions are not Frequency Control bypassed when THERMAL POWER is Program
~ 35.4% RTP.
(continued) GRAND GULF 3.3-5 Amendment No. 191, 197, Page 16 of 162
RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.1.15 ---------------------------NOT ES------------------------------
- 1. Neutron detectors are excluded.
- 2. For Functions 3, 4, and 5 in Table 3.3.1.1-1, the channel sensors may be excluded.
Verify the RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.16 Deleted SR 3.3.1.1.17 Perform APRM recirculation flow transmitter In accordance with calibration. the Surveillance Frequency Control Program SR 3.3.1.1.18 Deleted SR 3.3.1.1.19 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-5a Amendment No. 188, 197, Page 17 of 162
RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.3.1.1.20 -------------------------------NOTE----------------------------
- 1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
- 2. For Functions 2.a, 2.b, and 2.c, the APRM/OPRM channels and the 2-0ut-Of-4 Voter channels are included in the CHANNEL FUNCTIONAL TEST.
- 3. For Functions 2.d and 2.f, the APRM/OPRM channels arid the 2-0ut-Of-4 Voter channels plus the flow input function, excluding the flow transmitters, are included in the CHANNEL FUNCTIONAL TEST.
Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-5b Amendment No.488, 191, 205, Page 18 of 162
RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 4) Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE
- 1. Intermediate Range Monitors
- a. Neutron Flux - High 2 3 H SR 3.3.1.1.1 ~ 122/125 SR 3.3.1.1.3 divisions of full SR 3.3.1.1.12 scale SR 3.3.1.1.13 5(a) 3 . SR 3.3.1.1.1 ~ 122/125 SR 3.3.1.1.4 divisions of full SR 3.3.1.1.12 scale SR 3.3.1.1.13
- b. lnop 2 3 H SR 3.3.1.1.3 NA SR 3.3.1.1.13 5(a) 3 SR 3.3.1.1.4 NA SR 3.3.1.1.13
- 2. Average Power Range Monitors
- a. Neutron Flux - High, 2 3(b) H SR 3.3.1.1.7 ~20% RTP Setdown SR 3.3.1.1.1 O(c)(d)
SR 3.3.1.1.19 SR 3.3.1.1.20
- b. Fixed Neutron 3(b) G ~R 3.3.1.1.2 ~ 119.3% RTP Flux-High SR 3.3.1.1.7 SR 3.3.1.1.1 O(c)(d)
SR 3.3.1.1.19 SR 3.3.1.1.20 (continued) (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. (b) Each channel provides inputs to both trip systems. (c) If the as-found channel setpoint is outside its pre-defined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. (d) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the NTSP are acceptable provided the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The NTSP and tne methodologies used to determine the as-found and as-left tolerances are specified in the Technical Requirements Manual. GRAND GULF 3.3-6 Amendment No. 4e9, 4-88, 191, 205, Page 19 of 162
RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 4) Reactor Protectio_n System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE
- 2. Average Power Range Monitors (continued)
- c. lnop 1,2 3(b) H SR 3.3.1.1.20 NA
- d. Flow Biased 3(b) G SR 3.3.1.1.2 (e), (f)
Simulated SR 3.3.1.1.7 Thermal Power - High SR 3.3.1.1.1 o<c)(d) SR 3.3.1.1.17 SR 3.3.1.1.19 SR 3.3.1.1.20
- e. 2-0ut-Of-4 Voter 1,2 2 H SR 3.3.1.1.13 NA SR 3.3.1.1.15 SR 3.3.1.1.19 SR 3.3.1.1.20
- f. OPRM Upscale ~ 16.8% RTP 3(b) J SR 3.3.1.1.7 (g)
SR 3.3.1.1.1 o<c)(d) _ SR 3.3.1.1.19 SR 3.3.1.1.20 (continued) (b) Each channel provides inputs to both trip systems. (c) If the as-found channel setpoint is outside its pre-defined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. (d) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared ' inoperable. Setpoints more conservative than the NTSP are acceptable provided the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The NTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Technical Requirements Manual. (e) Two-Loop Operation: 0.64W + 61.8% RTP and:::;; 113% RTP Single-Loop Operation: 0.58W + 37.4% RTP (f) With the OPRM Upscale trip function (Function 2.f) inoperable, reset the APRM Flow Biased Simulated Thermal Power - High trip function (Function 2.d) setpoints to the values defined by the COLR to implement the Automated BSP Scram Region in accordance with Action J of this specification. (g) The setpoint for the OPRM Upscale Confirmation Density Algorithm (CDA) is specified in the COLR. GRAND GULF 3.3-6a Amendment No. 488, 191, 205, Page 20 of 162
RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 3 of 4) Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM
. SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE
- 3. Reactor Vessel Steam 1,2 2 H SR 3.3.1.1.1 ~ 1079.7 psig Dome Pressure - High SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 4. Reactor Vessel Water 1,2 2 H SR 3.3.1.1.1 ~ 10.8 inches Level-Low, Level3 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15 i
- 5. Reactor Vessel Water ~21.8% RTP 2 F SR 3.3.1.1.1 ~ 54.1 inches Level - High, Level 8 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 6. Main Steam Isolation 8 G SR 3.3.1.1.8 ~ 7% closed Valve - Closure SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 7. Drywall Pressure - High 1,2 2 H SR 3.3.1.1.1 ~ 1.43 psig SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13
- 8. Scram Discharge Volume Water Level - High
- a. Transmitter/Trip Unit 1,2 2 H SR 3.3.1.1.1 ~ 63% of full SR 3.3.1.1.8 scale SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 5(a) 2 SR 3.3.1.1.1 ~ 63% of full SR 3.3.1.1.8 scale SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 (continued)
(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. GRAND GULF 3.3-7 Amendment No. 120, 191, Page 21 of 162
RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 3 of 4) Reactor Protection System Instrumentation I I APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION 0.1 REQUIREMENTS VALUE
- 3. Reactor Vessel Steam 1,2 2 H SR 3.3.1.1.1 s 1079.7 psig Dome Pressure - High SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 4. Reactor Vessel Water 1,2 2 H SR 3.3.1.1.1 ~ 10.8 inches Level - Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 5. Reactor Vessel Water ~21.8% RTP 2 F SR 3.3.1.1.1 s 54.1 inches Level - High, Level 8 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 6. Main Steam Isolation 1 8 G SR 3.3.1.1.8 s7% closed Valve - Closure SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15
- 7. Drywell Pressure - High 1,2 2 H SR 3.3.1.1.1 s 1.43 psig SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13
- 8. Scram Discharge Volume Water Level - High
- a. Transmitter/Trip Unit 1,2 2 H SR 3.3.1.1.1 s 63% of full SR 3.3.1.1.8 scale SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 5(a) 2 SR 3.3.1.1.1 s 63% of full SR 3.3.1.1.8 scale SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 (continued)
(a} With any control rod withdrawn from a core cell containing one or more fuel assemblies. GRAND GULF 3.3-7 Amendment No. 120, 191, Page 22 of 162
RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 4 of 4) Reactor Protection ,System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE
- 8. Scram Discharge Volume Water Level - High (continued)
- b. Float Switch 1,2 2 H SR 3.3.1.1.8 :::; 65 inches.
SR 3.3.1.1.12 SR 3.3.1.1.13 5{a) 2 SR 3.3.1.1.8 :::; 65 inches SR 3.3.1.1.12 SR 3.3.1.1.13
- 9. Turbine Stop Valve ~ 35.4% RTP 4 E SR 3.3.1.1.8 ~ 37 psig Closure Trip Oil SR 3.3.1.1.9 Pressure - Low SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15
- 10. Turbine Control Valve ~ 35.4% RTP 2 E SR 3.3.1.1.8 ~ 42 psig Fast Closure, Trip Oil SR 3.3.1.1.9 Pressure - Low SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15
- 11. Reactor Mode Switch - 1,2 2 H SR 3.3.1.1.11 NA Shutdown Position SR 3.3.1.1.13 5{a) 2 SR 3.3.1.1.11 NA SR 3.3.1.1.13
- 12. Manual Scram 1,2 2 H SR 3.3.1.1.4 NA SR 3.3.1.1.13 5{a) 2 I SR 3.3.1.1.4 NA SR 3.3.1.1.13 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.
GRAND GULF 3.3-8 Amendment No. 120, 191, Page 23 of 162
SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS
- ---------------------------------------- . ------------------NOTE-------------------- .--------------------------------------
Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions. SURVEILLANCE FREQUENCY __/ SR 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2.2 -----------------------------NOTES----------------------------
- 1. Only required to be met during CORE AL TERATIONS.
- 2. One SRM may be used to satisfy more than on,e of the following.
Verify an OPERABLE SRM detector is located in: In accordance with the Surveillance
- a. The fueled region\; Frequency Control Program
- b. The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region; and
- c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.
SR 3.3.1.2.3 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-11 Amendment No. ~ , Page 24 of 162
SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.2.4 -----------------------------NO TE------------------------------ Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant. Verify count rate is: In accordance with the Surveillance a., ;;;:: 3.0 cps, or Frequency Control Program
- b. ;;;:: 0.7 cps with a signal to noise ratio;;;:: 2:1.
SR 3.3.1.2.5 -----------------------------NOTE---------------------,-------- Not required to be performed until 12 hours after IRMs on Range 2 or below. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2.6 -----------------------------NO TES----------------------------
- 1. Neutron detectors are excluded.
- 2. Not required to be performed until 12 hours after IRMs on Range 2 or below.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-12 Amendment No. ~ , 497, Page 25 of 1.62
Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS
NOTE 8----------------------------------------------------- .------
- 1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains control rod block capability.
SURVEILLANCE FREQUENCY SR 3.3.2.1.1 ------------------------------NOTE----------------------------- Not required to be performed until 1 hour after THERMAL POWER is greater than the RWL high power setpoint (HPSP) .. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.2 -----------* ------------------NO TE----------------------------- Not required to be performed until 1 hour after THERMAL POWER is > 35% RTP and less than or equal to the RWL HPSP. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.3 .-----------------------------NOTE----------------------------- Not required to be performed until 1, hour after any control rod is withdrc:1wn at s 10% RTP in MODE 2. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-15 Amendment No. 4-20, Page 26 of 162
Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.2.1.4 ---------------------------NO TE---------------------* ---------- Not required to be performed until 1 hour after THERMAL POWER is s 10% RTP in MODE 1. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.5 Calibrate the low power setpoint trip units. The In accordance with Allowable Value shall be ~ 10% RTP and the Surveillance s 35% RTP. Frequency Control Program
- SR 3.3.2.1.6 Verify the RWL high power Function is not In accordance with bypassed when THERMAL POWER is> 70% RTP. the Surveillance Frequency Control Program SR 3.3.2.1. 7 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.8 ---------------------------NOTE-------------------------------
Not required to be performed until 1 hour after reactor mode switch is in the shutdown position. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-16 Amendment No. 120, 197, Pag*e 27 of 162
PAM. Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS
,------------------------------------------------NOTE '-------------------------------------------------------------
These SRs apply to each Function in Table 3.3.3.1-1. SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.3.1.2 Deleted SR 3.3.3.1.3 ---------------------------NOTE--------------------- ,, --------- Neutron detectors are excluded. Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program
)
GRAND GULF 3.3-21 Amendment No. 166, 197, Page 28 of 162
Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE. APPLICABILITY: MODES 1 and 2. ACTIONS.
NOTE-------------------------------------------------------------
Se para te Condition entry is allowed for each Function*: CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30 days Functions inoperable. to OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required In accordance with
- instrumentation channel that is normally energized. the Surveillance Frequency Control Program (continued)
GRAND GULF 3.3-23 Amendment No. 120, .11§., Page 29 of 162
Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.3.2.2 Verify each required control circuit and transfer In accordance with switch is capable of performing the intended 1 the Surveillance functions. Frequency Control Program SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each In accordance with required instrumentation channel. the Surveillance Frequency Control Program GRAND GULF 3.3-24 Amendment No. 120, 197, Page 30 of 162
EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS
NOTE-------------------------------------------------------------
W hen a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided, the associated Function maintains EOC-RPT trip capability. SURVEILLANCE FREQUENCY SR 3.3.4.*1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.2 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.3 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: , the Surveillance Frequency Control
- a. TSV Closure, Trip Oil Pressure - Low: Program
~ 37 psig.
- b. TCV Fast Closure, Trip Oil Pressure -
Low: ~ 42 psig. SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance with including breaker actuation. the Surveillance Frequency Control Program SR 3.3.4.1.5 Verify TSV Closure, Trip Oil In accordance with Pressure - Low a'nd TCV Fast Closure, Trip Oil the Surveillance Pressure - Low Functions are not bypassed when Frequency Control THERMAL POWER is~ 35.4% RTP. Program i (continued) GRAND GULF 3.3-27 Amendment No. 120, 197, Page 31 of 162
EOC-RPT lnst.rumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.4.1.6 -----------------------------NOTE------------------- *---------- 8 rea ke r interruption time may be assumed from the most recent performance of SR 3.3.4.1.7. Verify the EOC-RPT SYSTEM RESPONSE TIME In accordance with is within limits. the Surveillance Frequency Control Program SR 3.3.4.1.7 Determine RPT breaker interruption time. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-28 Amendment No. 120, 197, Page 32 of 16_2-
ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One Function with 8.1 Restore ATWS-RPT trip 72 hours ATWS-RPT trip capability. capability not
- maintained ..
C. Both Functions with C.1 Restore ATWS-RPT trip 1 hour ATWS-RPT trip capability for one capability not Function. maintained. D. Required Action and D.1 Remove the associated 6 hours associated Completion recirculation pump from Time not met. service. OR D.2 Be in MODE 2. -_6 hours SURVEILLANCE REQUIREMENTS
------------------------------------NOTE------------------------------------------------------------
W hen a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability. SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-30 Amendment No. 420, Page 33 of 162
ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control
. Program SR 3.3.4.2.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program
( SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance. Frequency Control
- a. Reactor Vessel Water Level - Low Low, Program Level 2: ~ -43.8 inches; and
- b. Reactor Vessel Pressure - High: s 1139 psig.
SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance with including breaker actuation. the Surveillance Frequency Control Program GRAND GULF 3_3.:.31 Amendment No. 120, 197, Page 34 of 162
ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS
.----------------------------------NOTES-----------------------------------------------------------
- 1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours for Functions other than 3.c, 3.f, 3.g, and 3.h, provided the associated Function or the redundant Function maintains ECCS initiation capability.
SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.3 Calibrate the trip unit. In accordance_ with the Surveillance Frequency Control Program SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-38 Amendment No. 120, *197, Page 35 of 162
RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS
*---NOTES-------- *---------------------------------------------------
- 1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 2 and 5; and (b) for up to 6 hours for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.
SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In 'accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-46 Amendment No. 120, 197, Page 36 of 162
Primary Containment and Drywall Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS
.-----------------. -------------------------N{)TES--------------*----~----------.----------------------------
- 1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Function.
- 2. ) When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains isolation capability.
SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Perform CHANNEL FUNCTl()NAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program I-SR 3.3.6.1.4 Perform CHANNEL CALIBRATl()N. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALI BRATl()N. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform L()GIC SYSTEM FUNCTl()NAL TEST. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-53 Amendment No. 163, 197, Page 37 of 162
Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continue~) SURVEILLANCE FREQUENCY SR 3.3.6.1.7 Perform CHANNEL CALIBRATION. In accordance with the Surveiltance Frequency Control Program SR 3.3.6.1.8 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.9 -----------------------------NOTE---------~-------------------- Channel sensors may be excluded. Verify the ISOLATION SYSTEM RESPONSE In accordance with TIME for main steam isolation valves is within the Surveillance limits. Frequency Control Program SR 3.3.6.1.10 ---------------------------NOTE---------------------------..-- On ly required to be performed when Function 5.b is not OPERABLE as allowed by Footnote (h).of Table 3.3.6.1-1. Verify the water level in upper containment pool is In accordance with
~ 22 feet, 8 inches above reactor pressure vessel the Surveillance flange. Frequency Control Program GRAND GULF 3.3-53a Amendment No. 163, 197, Page 38 of 162
Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.1.2 Declare associated 1 hour secondary containment isolation valve(s) inoperable. AND C.2.1 Place the associated 1 hour standby gas treatment (SGT) subsystem in operation. OR C.2.2 Declare associated SGT 1 hour subsystem inoperable. SURVEILLANCE REQUIREMENTS
,--------------------------------------------------NOTES------------------------------------------------------------
- 1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains secondary containment isolation capability. '
SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-60 Amendment No. 420, Page 39 of 162
Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program j SR 3.3.6.2.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. In accordance with I the Surveillance Frequency Control Program SR 3.3.6.2.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2. 7 ------------------------. ----NOTE------------------------------ Radiation detectors may be excluded. Verify the ISOLATION SYSTEM RESPONSE TIME In accordance with for air operated secondary containment isolation the Surveillance dampers is within limits. Frequency Control Program GRAND GULF 3.3-61 Amendment No. 120, 197, Page 40 of 162
RHR Containment Spray System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS
-------- -.-------------------------------------------------NOTE 8----------------------------------------------------------
.- - - 1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each RHR Containment Spray System Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains RHR containment spray initiation capability.*
SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program
/
SR 3.3.6.3.5
- Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-65 Amendment No. 120, 197, Page 41 of 162
SPMU System Instrumentation I 3.3.6.4 I SURVEILLANCE REQUIREMENTS
NOTES----------------------------------------------------------
- 1. Refer to Table 3.3.6.4-1 to determine which SRs apply for each SPMU Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains SPMU initiation capability.
SURVEILLANCE FREQUENCY I SR 3.3.6.4.1 Perform CHANNEL CHECK. In accordance with
/
the Surveillance Frequency Control Program SR 3.3.6.4.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with I the Surveillance Frequency Control Program SR 3.3.6.4.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-69 Amendment No. 120, 197, Page 42 of 162
Relief and LLS Instrumentation 3.3.6.5. SURVEILLANCE REQUIREMENTS
NOTE--------------------------------------------- , ------------
When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains LLS or relief initiation capability, as applicable. SURVEILLANCE FREQUENCY SR 3.3.6.5.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.5.2 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program,_\ SR 3.3.6.5.3 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance Frequency Control
- a. Relief Function Program Low: 1103 +/- 15 psig Medium: 1113 +/- 15 psig High: 1123 +/- 15 psig
- b. LLS Function Low open: 1033 +/- 15 psig close: 926 +/- 15 psig Medium open: 1073 +/- 15 p~ig close: 936 +/- 15 psig High open: 1113 +/- 15 psig close: 946 +/- 15 psig SR 3.3.6.5.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-72 Amendment No. 120, 197, Page 43 of 162
CRFA System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS
---' --------------------------------------------------------NOTE-----------------------------------------------------------
W hen a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided CR isolation capability is maintained. SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 1 GRAND GULF 3.3-74 Amendment No. 145, 197, Next page is 3.3-77 Page 44 of 162
LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS
NOTES----------------------------------------------------------
- 1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains DG initiation capability.
SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.3 'Perform CHANNEL CALIBRATION. In accordance with the Surveillance Freq'uency Control Program SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GlJLF 3.3-78 Amendment No. 120, 197, Page 45 of 162
RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. _Required Action and D.1 Initiate action to fully insert Immediately associated Completion all insertable control rods in Time of Condition A or core cells containing one or B not met in MODE 4 more fuel assemblies. or 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 -----------------------------NOTE--. --------------------------- 1 Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for
~ 24 hours.
Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.3-81 Amendment No. 42-Q., Page 46 of 162
RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance Frequency Control
- a. Overvoltage Program Bus As 132.9 V Bus B s 133.0 V
- b. *Undervoltage Bus A~ 115.0 V Bus B ~ 115.9 V
- c. Underfrequency (with time delay set to s 4 seconds)
Bus A~ 57 Hz Bus B ~ 57 Hz (, SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.3-82 Amendment No. 120, 197, Page 47 of 162
Recirculation Loops Operating 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 ------------* ------------------NOTE--------*---------------------- Not required to be performed until 24 hours after both recirculation loops are in operation. Verify recirculation loop jet pump flow mismatch with In accordance with both recirculation loops in operation is: the Surveillance Frequency Control
- a. s 10% of rated core flow when operating at Program
< 70% of rated core flow; and
- b. s 5% of rated core flow when operating at
~ 70% of rated core flow.
- _/
GRAND GULF 3.4-4 Amendment No. 120, .111, Next page is 3.4-6 Page 48 of 162
FCVs 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs) LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop. APPLICABILITY: MODES 1 and 2. ACTIONS
,-------------------------NOTE-------------------------------------------------------------
Sepa rate Condition entry is 'allowed for each FCV. CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Lock up the FCV. 4 hours FCVs inoperable. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion ' Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 - Verify each FCV fails "as is" on loss of hydraulic In accordance with pressure at the hydraulic unit. the Surveillance Frequency Control Program (continued) GRAND GULF 3.4-6 Amendment No. 120, 197, Page 49 of 162
FCVs 3.4.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.4.2.2 Verify average rate of each FCV movement is: I In accordance with the Surveillance
- a. s 11 % of stroke per second for opening; and Frequency Control Program
- b. s 11 % of stroke per second for closing.
GRAND GULF 3.4-7 Amendment No. 120, 197, Page 50 of 162
Jet Pumps 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 -----------------------. -------NOTES---* -------------------------
- 1. Not required to be performed until 4 hours after associated recirculation loop is in operation.
- 2. Not required to be performed until 24 hours after> 21.8% 'RTP.
r Verify at least two of the following criteria (a, b, and In accordance with c) are satisfied for each operating recirculation loop: the Surveillance Frequency Control
- a. Recirculation loop drive flow versus flow control Program valve position differs by s 10% from established patterns.
- b. Recirculation loop drive flow versus total ~ore flow differs by s 10% from established patterns.
- c. Each jet pump diffuser to lower plenum differential pressure differs by s 20% from established patterns, or each jet pump flow differs b~)s 10% from established patterns.
GRAND GULF 3.4-9 Amendment No. 120, 191, Page 51 of 162
S/RVs 3.4.4 SURVEILLANCE REQUIREMENTS {continued) SURVEILLANCE FREQUENCY SR 3.4.4.2 -------------------------------NOTE------------------------------- Va Ive actuation may be excluded. Verify each required relief function S/RV actuates on In accordance with an actual or simulated automatic initiation signal. the Surveillance Frequency Control Program SR 3.4.4.3 -------------------------------NOTE-------------------------------- Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify each required S/RV relief-mode actuator In accordance with strokes when manually actuated. the INSERVICE TESTING PROGRAM on a STAGGERED TEST BASIS for each valve solenoid I GRAND GULF 3.4-11 Amendment No. 130, 197, Page 52 of 162
RCS Operational LEAKAGE 3.4.5 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or AND B not met. C.2 Be in MODE 4. 36 hours Pressure boundary LEAKAGE exists. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified LEAKAGE, total LEAKAGE, In accordance with and unidentified LEAKAGE increase are within the Surveillance limits. Frequency Control Program GRAND GULF 3.4-13 Amendment No. ~ , Page 53 of 162
RCS Leakage Detection Instrumentation 3.4.7 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Required drywell E.1 Restore required drywell 30 days atmospheric atmospheric monitoring monitoring system system to OPERABLE inoperable. status. AND OR Drywell air cooler E.2 Restore drywell air cooler 30 days condensate flow rate condensate flow rate monitoring system monitoring system to inoperable. OPERABLE status. F. Required Action and F.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, AND B, C, D, or E not met. F.2 Be in MODE 4. 36 hours G. All required leakage G.1 Enter LCO 3.0.3 Immediately detection systems inop~rable. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell In accordance with atmospheric monitoring system. the Surveillance Frequency Control Program (continued) GRAND GULF 3.4-18 Amendment No. 187, 197, Page 54 of 162
RCS Leakage Detection Instrumentation 3.4.7 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME I
~'
E. Required drywall E.1 Restore required drywall 30 days
- atmospheric atmospheric monitoring monitoring system system to OPERABLE inoperable. status.
AND OR Drywall air cooler E.2 Restore drywall air cooler 30 days condensate flow rate condensate flow rate monitoring system monitoring system to inoperable. OPERABLE status. F. Required Action and F.1 Be in MODE 3. 12 hours associated Completion Time of Condition A,
- AND B, C, D, or E not met.
F.2 Be in MODE 4. 36 hours G. All required leakage G.1 Enter LCO 3.0.3 Immediately detection systems inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywall In accordance with atmospheric monitoring system. the Surveillance , Frequency Control Program (continued) GRAND GULF 3.4-18 Amendment No. 187, 197, Page 54 of 162
RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of In a~cordance with required leakage detection instrumentation. the Surveillance Frequency Control Program SR 3.4.7.3 Perform CHANNEL CALIBRATION of required In accordance. with leakage detection instrumentation. the Surveillance Frequency Control Program GRAND GULF 3.4-18a Amendment No. Page 55 of 162
RCS Specific Activity
. 3.4.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 -------------------------------NOTE-------------------------------
O nIy required to be performed in MODE 1. Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance with specific activity is s 0.2 µCi/gm. the Surveillance Frequency Control Program GRAND GULF 3.4-20 Amendment No. ~ ' Page 56 of 162
RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 -----------------------------NO TE------------------------------ Not required to be met until 2 hours after reactor steam dome pressure is less than the RHR cut in permissive pressure. Verify one RHR shutdown cooling subsystem or In accordance with recirculation pump is operating. the Surveillance Frequency Control Program SR 3.4.9.2 ------------------------------NOTE---------------------------- .- Not required to be performed until 12 hours after reactor steam dome pressure is < the RH R cut in permissive pressure. Verify RHR shutdown cooling subsystem locations In accordance with susceptible to gas accumulation are sufficiently filled the Surveillance with water. Frequency Control Program GRAND GULF 3.4-23 Amendment No. 120, 202, Page 57 of 162
RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown 8.1 Verify reactor coolant 1 hour from discovery cooling subsystem in circulating by an of no reactor coolant operation. alternate method. circulation AND AND No recirculation pump Once per in operation. 12 hours thereafter AND 8.2 Monitor reactor coolant Once per hour temperature and pressure. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or In" accordance with recirculation pump is operating. the Surveillance Frequency Control Program SR 3.4.10.2 Verify RHR shutdown cooling subsystem locations In accordance with susceptible to gas accumulation are sufficiently the Surveillance* filled with water.
- Frequency Control Program GRAND GULF 3.4-25 . Amendment No. 120, 202, Page 58 of 162
RCS PIT Limits 3.4.11 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. ----------NOTE----------- C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed if limits specified in the this Condition is PTLR. entered.
----------------------------- AND Requirements of the C.2 Determine RCS is Prior to entering LCO not met in other acceptable for operation. MODE 2 or 3 than MODES 1, 2, and 3.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------------------NO TE------------------------------ O nly required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing. Verify: In accordance with the Surveillance
- a. RCS pressure and RCS temperature are Frequency Control within the limits specified in the PTLR based Program on the current effective full power year (EFPY), and
- b. RCS heatup and cooldown rates are within the limits specified in the PTLR.
(continued) GRAND GULF 3.4-27 Amendment No. 42Q, 1d2, 191, Page 59 of 162
RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.4.11.2 -------------------------------NOTE-------------------------------- O nly required to be met during control rod withdrawal for the purpose of achieving criticality. Verify RCS pressure and RCS temperature are within Once within 15 the criticality limits specified in the PTLR based on the minutes prior to on the current EFPY. control rod withdrawal for the purpose of achieving criticality SR 3.4.11.3 ------------------------------NOTE-------------------------------- O nly required to be met in MODES 1, 2, 3, and 4 with reactor steam dome pressure ~ 25 psig during recirculation pump start. Verify the difference between the bottom head Once within 15 coolant temperature and the reactor pressure vessel minutes prior to (RPV) coolant temperature is within the limits each startup of a specified in the PTLR. recirculation pump SR 3.4.11.4 -------------- *---------------NOTE-------------------------------- O n ly required to be met in MODES 1, 2, 3, and 4 during recirculation pump start. Verify the difference between the reactor coolant *Once within 15 temperature in the recirculation loop to be started minutes prior to and the RPV coolant temperature is within the limits each startup of a specified in the PTLR.
- recirculation pump (continued)
GRAND GULF 3.4-28 Amendment No. 420, 1a2, 191, Page 60 of 162
RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.4.11.5 ------------* -----------------NOTE-----------------* -------------- Only required to be performed when tensioning the reactor vessel head bolting studs. Verify reactor vessel flange and head In accordance with flange temperatures are within the limits the Surveillance specified in the PTLR. Frequency Control Program SR 3.4.11.6 ------------------------------NOTE-* ------------------------------ Not required to be performed until 30 minutes after RCS temperature s 80°F in MODE 4. Verify reactor vessel flange and head flange In accordance with temperatures are within the limits specified in the the Surveillance PTLR. Frequency Control Program SR 3.4.11.7 ------------------------------NOTE-------------------------------- Not required to be performed until 12 hours after RCS temperature s 100°F in MODE 4. Verify reactor vessel flange and head flange In accordance with temperatures are within the limits specified in the the Surveillance PTLR. Frequency Control Program (continued) GRAND GULF 3.4-29 Amendment No. 120, 191, Page 61 of 162
Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be s 1045 psig. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME
-~
A. Reactor steam dome A.1 Restore reactor steam
- 15 minutes pressure riot within dome pressure to within limit. limit.
B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE .FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is In accordance with s 1045 psig. the Surveillance Frequency Control Program GRAND GULF 3.4-36 Amendment No. 120, 132, Page 62 of 162
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program SR 3.5.1.2 -------------------------------NOTE------------------------------- Not required to be met for system vent flow paths opened under administrative control. Verify each ECCS injection/spray subsystem manual, In accordance with power operated, and automatic valve in the flow path, the Surveillance that is not locked, sealed, or otherwise secured in Frequency Control position, is in the correct position. Program SR 3.5.1.3 Verify ADS accumulator supply pressure is In accordance with
~ 150 psig. the Surveillance Frequency Control Program
. SR 3.5.1.4 Verify each ECCS pump develops the specified flow In accordance with rate with the specified total developed head. the INSERVICE TESTING Total PROGRAM System Flow Rate Developed Head LPCS ~ 7115 gpm ~ 290 psid LPCI ~ 7450 gpm ~ 125 psid HPCS ~ 7115 gpm ~ 445 psid (continued) GRAND GULF 3.5-4 Amendment No. 420, 4-e-9, 202, 211, Page 63 of 162
ECCS - Operating 3.5.1 SURVEILLANCE- REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.5.1.5 -------------------------------NOTE------------------------------- Vessel injection/spray may be excluded. Verify each ECCS injection/spray subsystem actuates In accordance with on an actual or simulated automatic initiation signal. the Surveillance Frequency Control Program SR 3.5.1.6 *----------- *------------------N()TE------------------------------- Valve actuation may be excluded. Verify the ADS actuates on an actual or simulated In accordance with automatic initiation signal. the Surveillance Frequency Control Program SR 3.5.1.7 -------------------------------N()TE------------------------------- Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify each ADS valve relief-mode actuator strokes In accordance with when manually actuated. the INSERVICE TESTING PR()GRAM on a STAGGERED TEST BASIS for each valve solenoid (continued) GRAND GULF 3.5-5 Amendment No. 4-Ja, 497, Page 64 of 162
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.1.8 -------------------------------NO TE------------------------------- ECCS Actuation instrumentation is excluded. Verify the ECCS RESPONSE TIME for HPCS In accordance with System is within limits. the Surveillance Frequency Control Program GRAND GULF 3.5-5a Amendment No. Page 65 of 162
ECCS - Shutdown 3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 D.1 Initiate action to restore Immediately and associated secondary containment to Completion Time not OPERABLE status. met. D.2 Initiate action to restore Immediately one standby gas treatment subsystem to OPERABLE status. D.3 Initiate action to restore Immediately isolation capability in each required secondary containment penetration flow path not isolated. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure ECCS In accordance with injection/spray subsystem, the suppression pool the Surveillance water level is ~ 12 ft 8 inches. Frequency Control Program (continued) GRAND GULF 3.5-7 Amendment No. ~ ' Page 66 of 162
ECCS - Shutdown 3.5.2 SURVEILLANCEREQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pressure Core Spray In accordance with (HPCS) System, the: the Surveillance , Frequency Control
- a. Suppression pool water level is ~ 12 ft 8 Program inches; or
- b. Condensate storage tank water level is ~ 18 ft.
SR 3.5.2:3 Verify, for each required ECCS injection/ spray In accordance with subsystem, locations susceptible to gas the Surveillance accumulation are sufficently filled with water. Frequency Control Program SR 3.5.2.4 -------------------------------NC>TE------------------------------ Not required to be met for system vent flow paths opened under administrative control. Verify each required ECCS injection/spray In accordance with subsystem manual, power operated, and automatic the Surveillance valve in the flow path, that is not locked, sealed, or Frequency Control otherwise secured in position, is in the correct Program position. (continued) GRAND GULF 3.5-8 Amendment No. 4-2-Q, 499, 202, Page 67 of 162
ECCS- Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the In accordance with specified flow rate with the specified total developed the INSERVICE head. TESTING PROGRAM Total System Flow Rate Developed Head LPCS ~ 7115 gpm ~ 290 psid LPCI ~ 7450 gpm ~ 125 psid HPCS ~ 7115 gpm ~ 445 psid SR 3.5.2.6 -------------------------------NO TE------------------------------- Vesse I injection/spray may be excluded. Verify each required ECCS injection/spray subsystem In accordance with actuates on an actual or simulated automatic initiation the Surveillance signal. Frequency Control Program GRAND GULF 3.5-9 Amendment No. ~ , 4-97, ~ 1 Page 68 of 162
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas In accordance with accumulation are sufficiently filled with water. the Surveillance Frequency Control Program SR 3.5.3.2 -------------------* -----------N()TE------------------------------- Not required to be met for system vent flow paths opened under administrative control. Verify each RCIC System manual, power operated, In accordance with and automatic valve in the flow path, that is not the Surveillance locked, sealed, or otherwise secured in position, is in Frequency Control the correct position. Program SR 3.5.3.3 -------------------------------N()TE------------------------------- Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with RCIC steam supply pressures 1045 psig In accordance with and ~ 945 psig, the RCIC pump can develop a flow the Surveillance rate ~ 800 gpm against a system head corresponding Frequency Control to reactor pressure. Program SR 3.5.3.4 -------------------------------N()TE------------------------------- Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with RCIC steam supply pressure s 165 psig In accordance with and ~* 150 psig, the RCIC pump can develop a flow the Surveillance rate ~ 800 gpm against a system head corresponding Frequency Control to reactor pressure. Program (continued) GRAND GULF 3.5-11 Amendment No. 420, 4-9+, ~ ' Page 69 of 162
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.3.5 * -------------------------------N()TE------------------------------- Vessel injection may be excluded.
)
Verify the RCIC System actuates on an actual or In accordance with simulated automatic initiation signal. the Surveillance Frequency Control Program GRAND GULF 3.5-12 Amendment No. ~ ' 49+, Page 70 of 162
Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 ------------------------------NOT ES---------------------------
- 1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.
- 2. Results shall be evaluated against
- acceptance criteria of SR 3.6.1.1.1 in accordance with 10 CFR 50, Appendix J, as modified by approved exemptions.
Perform required primary containment air lock In accordance with leakage rate testing in accordance with 10 CFR 50, 10 CFR 50, Appendix J, as modified by approved exemptions. Appendix J, Testing Program The acceptance criteria for air lock testing are:
- a. Overall air lock leakage rate is s 0.05 La when tested at~ Pa.
- b. For each door, leakage rate is s 0.01 La when the gap between the door seals is pressurized to~ Pa.
SR 3.6.1.22 Verify primary containment air lock seal air flask In accordance with pressure is ~ 90 psig. the Surveillance Frequency Control Program (continued) GRAND GULF
- 3.6-7 Amendment No. 4-d& 4-68, Page 71 of 162
Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.1.2.3 Verify only one door in the primary containment air In accordance with lock can be opened at a time. the Surveillance Frequency Control Program SR 3.6.1.2.4 Verify, from an initial pressure of 90 psig, the In accordance with primary containment air lock seal pneumatic the Surveillance system pressure does not decay at a rate Frequency Control equivalent to > 2 psig for a period of 48 hours. Program GRAND GULF 3.6-8 Amendment No. 142, 197, Page 72 of 162
PC IVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY. SR 3.6.1.3.1 -----------------------------NOT ES----------------------------
. 1. .Only required to be met in MODES 1, 2, and 3.
- 2. Not required to be met when the 20 inch primary containment purge valves are open for pressure control, ALARA, or air qm~lity considerations for personnel entry.
- 3. Not required to be met during Surveillances or special testing on the purge system that requires the valves to be open.
- 4. 20 inch primary containment purge valves shall not be open with 6 inch primary containment purge or drywell vent and purge supply and exhaust lines open.
Verify each 20 inch primary containment purge ** 1n accordance with valve is closed.
- the Surveillance Frequency Control Program SR 3.6.1.3.2 -----------------------------NO TES----------------------------
- 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
- 2. Not required to be met for PCIVs that are open under administrative controls.
Verify each primary containment isolation manual In accordance with valve and blind flange that is located outside the Surveillance primary containment, drywell, and steam tunnel Frequency Control and not locked, sealed, or otherwise secured and is Program required to be closed during accident conditions is closed. (continued) GRAND GULF 3.6-14 Amendment No. 120, .111, Page 73 of 162
PC IVs 3.6.1.3 SURVEILLANCE REQUIREMENTS . continued SURVEILLANCE FREQUENCY SR 3.6.1.3.5 -----------------------------NOTE------------------------------ . Only required to be met in MODES 1, 2, and 3.
' Perform leakage rate testing for each primary In accordance with containment purge valve with resilient seals. the Surveillance Frequency Control Program*
In accordance with 10 CFR 50, Appendix J, Testing Program AND
--------NO TE--------
Not applicable to valves Jested within 92 days prior to any purge valve failing to meet its acceptance criteria Once within 92 days, test all remaining purge valves, if any purge valve fails to meet its acceptance criteria (continued) GRAND GULF 3.6-16 Amendment No. ~.128 ~ ' Page 74 of 162
PC IVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.1.3.6 Verify the isolation time of each MSIV is ~ 3 In accordance with seconds and s 5 seconds. the INSERVICE TESTING PROGRAM SR 3.6.1.3.7 Verify each automatic PCIV actuates to the In accordance with isolation position on an actual or simulated isolation the Surveillance signal. Frequency Control Program SR 3.6.1.3.8 -----------------------------NOTE------------------------------ O nly required to be met in MODES 1, 2, and 3. Verify leakage rate through each main steam line is In accordance s 100 scfh when tested at~ Pa, and the total with 10 CFR 50, leakage rate through all four main steam lines is Appendix J, s 250 scfh when tested at~ Pa. Testing Program SR 3.6.1.3.9 -----------------------------NOTE------------------------------ O nly required to be met in MODES 1, 2, and 3. Verify combined leakage rate of 1 gpm times the In accordance total number of PCIVs through hydrostatically with 10 CFR 50, tested lines that penetrate the primary containment Appendix J, is not exceeded when these isolation valves are Testing Program tested at~ 1.1 Pa. GRAND GULF 3.6-17 Amendment No. ~ ' 197, 211, Page 75 of 162
Primary Containment Pressure 3.6.1.4 3.6 CONTAIN~ENT SYSTEMS 3.6.1.4 Primary Containment Pressure LCO 3.6.1.4 Primary containment to auxiliary building differential pressure shall be
~ - 0.1 psid ands 1.0 psid.
APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment to A.1 Restore primary 1 hour auxiliary building containment to auxiliary differential pressure not building differential pressure within limits. to within limits. B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify primary containment to auxiliary building In accordance with differential pressure is within limits. the Surveillance Frequency Control Program GRAND GULF 3.6-18 Amendment No. ~ ' Page 76 of 162
Primary Containment Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Primary Containment Air Temperature LCO 3.6.1.5 Primary containment average air temperature shall be s 95°F. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 8 hours average air temperature containment average air not within limit. temperature to within limit. I B. Required Action and
- B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify primary containment average air temperature In accordance with is within limit. the Surveillance Frequency Control Program GRAND GULF 3.6-19 Amendment No. 420, Page 77 of 162
LLS Valves 3.6.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 -----------------------------NOTE------------------------------ Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to* perform the test. Verify each LLS valve relief-mode actuator strokes In accordance with when manually actuated. the INSERVICE TESTING PROGRAM on a STAGGERED TEST BASIS for each valve solenoid SR 3.6.1.6.2 -----------------------------NOTE------------------------------ Va Ive actuation may be excluded. Verify the LLS System actuates on an actual or In accordance with simulated automatic initiation signal. the Surveillance Frequency Control Program GRAND GULF 3.6-21 Amendment No. 130, 197, Page 78 of 162
RHR Containment Spray System
. 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 -------------------------------NOTE---------------------. ------
- 1. RHR containment spray subsystems may be considered OPERABLE during alignment and operation for decay heat removal when below the RHR cut in permissive pressure in MODE 3 if capable of being manually realigned and not otherwise inoperable.
- 2. Not required to be met for system vent flow paths opened under administrative control.
Verify each RHR containment spray subsystem In accordance with manual, power operated, and automatic valve in the Surveillance the flow path that is not locked, sealed, or Frequency Control otherwise secured in position is in the correct Program position. SR 3.6.1.7.2 Verify RHR containment spray subsystem locations In accordance with susceptible to gas accumulation are sufficiently filled the Surveillance with water. Frequency Control Program SR 3.6.1.7.3 Verify each RHR pump develops a flow rate of In accordance with
~ 7450 gpm on recirculation flow through the the INSERVICE associated heat exchanger to the suppression TESTING pool. PROGRAM SR 3.6.1.7.4 Verify each RHR containment spray subsystem In accordance with automatic valve in the flow path actuates to its the Surveillance correct position on an actual or simulated Frequency Control automatic initiation signal. Program (continued)
GRAND GULF 3.6-23 Amendment No. ~ , 497, 202, 211, Page 79 of 162
RHR Containment Spray System 3.6.1.7 SURVEILLANCE REQUIREMENTS continued . SURVEILLANCE FREQUENCY SR 3.6.1.7.5 Verify each spray nozzle is unobstructed. _/ At first refueling In accordance with the Surveillance Frequency Control Program GRAND GULF 3.6-23a Amendment No. Page 80 of 162
FWLCS 3.6.1.8 3.6. CONTAINMENT SYSTEMS 3.6.1.8 Feedwater Leakage Control System (FWLCS) LCO 3.6.1.8 Two FWLCS subsystems shall be OPERABLE. . APPLICABILITY: MODES 1,2, and 3. ACTIONS
'\ CONDITION REQUIRED ACTION COMPLETION TIME A. One FWLCS subsystem A.1 Restore FWLCS 30 days inoperable. subsystems to OPERABLE status.
B. Two FWLCS subsystems 8.1 Restore one FWLCS 7 days inoperable. subsystem to OPERABLE status. C. Required Action and C.1 --------------NOTE--------------- associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3. Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.8.1 Verify RHR jockey pump operates properly. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.6-24 Amendment No. 120, 201, Page 81 of 162
MSIVLCS 3.6.1.9 3.6 CONTAINMENT SYSTEMS 3.6.1.9 Main Steam Isolation Valve (MSIV) Leakage Control System (LCS) LCO 3.6.1.9 Two MSIV LCS subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIVLCS A.1 Restore MSIV LCS 30 days subsystem inoperable. subsystem to OPERABLE status. B. Two MSIV LCS 8.1 Restore one MSIV LCS 7 days subsystems inoperable. subsystem to OPERABLE status. C. Required Action and C.1 --------------NO TE---------- ,---- associated Completion LCO 3.0.4.a_is not Time not met. applicable when entering MODE 3. Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.9.1 Operate each outboard MSIV LCS blower ~ 15 In accordance with minutes. the Surveillance Frequency Control Program (continued) GRAND GULF 3.6-25 Amendment No. 420 122, 201, Page 82 of 162
MSIV LCS 3.6.1.9 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.1.9.2 Perform a system functional test of each MSIV LCS In accordance with subsystem. the Surveillance Frequency Control Program GRAND GULF 3.6-26 Amendment No. 122, 197, Page 83 of 162
Suppression Pool Average Temperature 3.6.2.1 SURVEI.LLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average temperature is In accordance with within the applicable limits. the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool GRAND GULF 3.6-29 Amendment No. 420, Page 84 of 162
Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2;2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be ~ 18 ft 4-1 /12 inches and s 18 ft 9-3/4 inches. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression pool 2 hours level not within limits. water level to within limits. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is within limits. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.6-30 Amendment No. 42-0, Page 85 of 162
RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance with subsystem manual, power operated, and automatic the Surveillance valve in the flow path that is not locked, sealed, or Frequency Control otherwise secured in position is in the correct Program position or can be aligned to the correct position. SR 3.6.2.3.2 Verify RHR suppression pool cooling subsystem In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program SR 3.6.2.3.3 Verify each RHR pump develops a flow rate In accordance with
~ 7450 g'pm through the associated heat the INSERVICE exchangers to the suppression pool. TESTING PROGRAM GRAND GULF 3.6-32 Amendment No. 420, 202, 211, Page 86 of 162
SPMU System 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.1 Verify upper containment pool water level is ~ 23 ft In accordance with 3 inches above the pool bottom. the Surveillance Frequency Control Program SR 3.6.2.4.2 Verify upper containment pool water temperature is In accordance with s 125°F. the Surveillance Frequency Control Program SR 3.6.2.4.3 Verify each SPMU subsystem manual, power In accordance with operated, and automatic valve that is not locked, the Surveillance sealed, or otherwise secured in positiqn is in the Frequency Control correct position. Program SR 3.6.2.4.4 -----------------------------NOTE------------------------------ Not required to be met when all upper containment pool levels are maintained per SR 3.6.2.4.1 and suppression pool water level is maintained ~ 18 ft 5 1/12 inches (one inch above LCO 3.6.2.2 Low Water Level). Verify all upper containment pool gates are in the In accordance with stored position or are otherwise removed from the the Surveillance upper containment pool. Frequency Control Program SR 3.6.2.4.5 -----------------------------NOTE------------------------------ Actu aI makeup to the suppression pool may be excluded. Verify each SPMU subsystem automatic valve In accordance with actuates to the correct position on an actual or the Surveillance simulated automatic initiation signal. Frequency Control Program GRAND GULF 3.6-34 Amendment No. 154, 197, Next page is 3.6-37 Page 87 of 162
Primary Containment and Drywell Hydrogen lgniters
. . 3.6.3.2 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.6.3.2.1 Energize each primary containment and drywell In accordance with hydrogen igniter division and perform current the Surveillance versus voltage measurements to verify required Frequency Control igniters in service. Program SR 3.6.3.2.2 -----------------------------NOTE------------------------------ Not required to be performed until 92 days after discovery of four or more igniters in the division inoperable. Energize each primary containment and drywell In accordance with hydrogen igniter division and perform current the Surveillance versus voltage measurements to verify required Frequency Control igniters in service. Program SR 3.6.3.2.3 Verify each required igniter in inaccessible areas In accordance with develops sufficient current draw for a ~ 1700°F the Surveillance surface temperature. Frequency Control Program (continued) GRAND GULF 3.6-38 Amendment No. 120, 197, Page 88 of 162
Primary Containment and Drywell Hydrogen lgniters 3.6.3.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.3.2.4 Verify each required igniter in accessible areas In accordance with develops a surface temperature of~ 1700°F. the Surveillance Frequency Control Program GRAND GULF 3.6-39 Amendment No. 120, 197, Page 89 of 162
Drywell Purge System 3.6.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3.1 Perform a CHANNEL FUNCTIONAL TEST of the In accordance with isolation valve pressure actuation instrumentation. tbe Surveillance Frequency Control Program SR 3.6.3.3.2 Operate each drywell purge subsystem for In accordance with
~ 15 minutes. the Surveillance Frequency Control Program SR 3.6.3.3.3 Verify each drywell purge subsystem flow rate is In accordance with
~ 1000 cfm.
- the Surveillance Frequency Control Program SR 3.6.3.3.4 Verify the opening pressure differential of each In accordance with vacuum breaker and isolation valve is s 1.0 psid. the Surveillance Frequency Control Program GRAND GULF 3.6-41 Amendment No. 120, 197, Page 90 of 162
Secondary Containment 3.6.4.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment C.1 --------------NOTE--------------- inoperable during LCO 3.0.3 is not applicable. movement of recently ------------------------------------- irradiated fuel assemblies in the Suspend movement of Immediately primary or secondary recently irradiated fuel containment or during assemblies in the primary OPDRVs. and secondary containment. AND C.2 Initiate action to suspend Immediately OPDRVs. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify all auxiliary building and enclosure building In accordance with
- equipment hatches and blowout panels are closed the Surveillance and sealed. Frequency Control Program
- SR 3.6.4.1.2 Verify one auxiliary building and enclosure building In accordance with access door in each access opening is closed, the Surveillance except when the access opening is being used for Frequency Control entry and exit. Program (continued)
GRAND GULF 3.6-43 Amendment No. 139,.111, Page 91 of 162
Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.4.1.3 Verify the secondary containment can be drawn In accordance with down to ~ 0.25 inch of vacuum water gauge in s 180 the Surveillance seconds using one standby gas treatment (SGT) Frequency Control subsystem. Program SR 3.6.4.1.4 Verify the secondary containment can be maintained In accordance with
~ 0.266 inch of vacuum water gauge for 1 hour using the Surveillance one SGT subsystem at a flow rates 4000 cfm. Frequency Control Program GRAND GULF 3.6-44 Amendment No. 169, 197, Page 92 of 162
SC IVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 ----------------------------NOT ES-----------------------------
- 1. Valves, dampers, rupture disks, and blind flanges in high radiation areas may be verified by use of administrative means.
- 2. Not required to be met for SCIVs that are open under administrative controls.
Verify each secondary containment isolation In accordance with manual valve, damper, rupture disk, and blind the Surveillance flange that is required to be closed during accident Frequency Control conditions is closed. Program SR 3.6.4.2.2 Verify the isolation time of each power operated, In accordance automatic SCIV is within limits. with the INSERVICE TESTING PROGRAM SR 3.6.4.2.3 . Verify each automatic SCIV actuates to the In accordance with
' isolation position on an actual or simulated the Surveillance automatic isolation signal. Frequency Control Program GRAND GULF 3.6-48 Amendment No. 4-69, 197, 211, Page 93 of 162
SGT System 3.6.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for ~ 15 continuous In accordance with minutes with heaters operating. the Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.6.4.3.3 Verify each SGT subsistem actuates on an actual In accordance with
. or simulated initiation signal. the Surveillance Frequency Control Program GRAND GULF 3.6-51 Amendment No. 4-2-0, 197, 208, Page 94 of 162
Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1.1 Verify bypass leakage is less than or equal to the 24 months following bypass leakage limit. two consecutive tests with bypass leakage However, during the first unit startup following greater than the drywell bypass leak rate testing performed in bypass leakage limit accordance with this SR, the acceptance criterion until two consecutive is leakage s 10% of the bypass leakage limit. tests are less than or equal to the bypass leakage limit 48 months following a test with bypass leakage greater than the bypass leakage limit AND
----------NOTE---------
SR 3.0.2 is not applicable for extensions
> 12 months.
In accordance with the Surveillance Frequency Control Program except next drywell bypass leak rate test performed after October 19, 2008 test shall be performed no later than plant restart after End of Cycle 22 Refueling Outage (continued) GRAND GULF 3.6-53 Amendment No. 4-29*, 121.i 209, 214,
*'.'Vith Correction Letter of 9/16/96 Page 95 of 162
Drywell 3.6.5.1
. . :. - ~. .........,..
SURVEILLANCE REQUIREMENTS (continued) ,-.. . .::: SURVEILLANCE FREQUENCY SR 3.6.5.1.2 Visually inspect the exposed accessible interior and Once prior to exterior surfaces of the drywell. performance of each Type A test required by SR 3.6.1.1.1 SR 3.6.5.1.3 Verify drywell air lock leakage by performing an air In accordance with I lock barrel leakage test at~ 3 psid. the Surveillance Frequency Control Program GRAND GULF 3.6-53a Amendment No. 4e4, Page 96 of 162
Drywell Air Lock . 3.6.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.2.1 -- _-------------------------NO TE------------------------------ O n ly required to be performed upon entry into drywell. Verify only one door in the drywell air lock can be In accordance with opened at a time. the Surveillance Frequency Control Program
)
GRAND GULF 3.6-57 Amendment No. 120, 126, Page 97 of 162
Drywell Isolation Valves
. 3.6.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE
- FREQUENCY SR 3.6.5.3.1 -----------------------------NO TES----------------------------
- 1. Not required to be met when the drywell purge supply or exhaust valves are open for pressure control, ALARA, or air quality considerations for personnel entry.
- 2. Not required to be met during Surveillances or special testing on the purge system that requires the valves to be open.
- 3. Drywell purge supply or exhaust valves shall not be open in MODES 1 and 2 with the 6 inch or 20 inch primary containment purge system purge supply and exhaust lines open.
Verify each 20 inch drywell purge isolation valve is In accordance with closed. the Surveillance Frequency Control Program SR 3.6.5.3.2 ----------------------------NOT ES--------------- .-------------
- 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
- 2. Not required to be met for drywell isolation valves that are open under administrative controls.
Verify each drywell isolation manual valve and blind Prior to entering flange that is required to be closed during accident MODE 2 or 3 from conditions is closed. MODE 4, if not performed in the previous 92 days (continued) GRAND GULF 3.6-60 Amendment No. ~ ' Page 98 of 162
Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued)
- SURVEILLANCE FREQUENCY SR 3.6.5.3.3 Verify the isolation time of each power operated, In accordance automatic drywell isolation valve is within limits. with the INSERVICE TESTING PROGRAM SR 3.6.5.3.4 Verify each automatic drywell isolation valve In accordance with actuates to the isolation position on an actual or the Surveillance simulated isolation signal. Frequency Control Program GRAND GULF 3.6-61 Amendment No. 4-e-9, 197, 211, Page 99 of 162
Drywell Pressure 3.6.5.4 3.6 CONTAINMENT SYSTEMS 3.6.5.4 Drywell Pressure ( LCO 3.6.5.4 Drywell-to-primary containment differential pressure shall be ~ - 0.25 psid and s 2.0 psid. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell-to-primary A.1 Restore drywell-to-primary 1 hour containment differential containment differential pressure not within pressure to within limits. limits. B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.4.1 Verify drywell-to-primary containment differential In accordance with pressure is within limits. the Surveillance Frequency Control Program GRAND GULF 3.6-62 Amendment No. ~ ' 4-a+, Page 100 of 162
Drywell Air Temperature 3.6.5.5 3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.*5 Drywell average air temperature shall bes 135°F. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell average 8 hours temperature not within air temperature to within limit. limit. B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCl= FREQUENCY SR 3.6.5.5.1 Verify drywell average air temperature is within In accordance with limit. the Surveillance Frequency Control Program GRAND GULF 3.6-63 Amendment No. ~ , Page 101 of 162
Drywell Vacuum Relief System 3.6.5.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.6.1 ----------------------------NO TES-----------------------------
- 1. Not required to be met for vacuum breakers or isolation valves open during surveillances.
- 2. Not required to be met for vacuum breakers or isolation valves open when performing their intended function.
Verify each vacuum breaker and its associated In accord_ance with isolation valve is closed. the Surveillance Frequency Control Program I SR 3.6.5.6.2 Perform a functional test of each vacuum breaker In accordance with and its associated isolation valve. the Surveillance Frequency Control Program SR 3.6.5.6.3 Verify the opening pressure differential of each In accordance with vacuum breaker and isolation valve is s 1.0 psid. the Surveillance Frequency Control Program GRAND GULF 3.6-67 Amendment No. ~ , 4-97, Page 102 of 162
SSW System and UHS 3.7.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME ( D. One SSW subsystem ----------- -------NO TES------------------- inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources - Operating," for diesel generator made inoperable by SSW.
- 2. Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown," for RHR shutdown cooling subsystem made inoperable by SSW.
D.1 Restore SSW subsystem to 72 hours OPERABLE status. E. Required Action and E.1 ---------------NOTE-------------- associated Completion LCO 3.0.4.a is not Time of Condition A, C, applicable when entering or D not met. MODE 3. Be in MODE 3. 12 hours (continued) GRAND GULF 3.7-2 Amendment No. 4-20, Page 103 of 162
SSW System and UHS 3.7.1 ACTIONS (ci>ritinued) *
- CONDITION REQUIRED ACTION COMPLETION TIME F Both SSW subsystems F.1 Be in MODE 3. 12 hours inoperable.
AND F.2 Be in MODE4. 36 Hours Two UHS cooling towers with one or more cooling tower fans inoperable. UHS basin inoperable for reasons other than Condition C. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level of each UHS basin is~ 7.25 ft. In accordance with the Surveillance
- Frequency Control Program SR 3.7.1.2 Operate each SSW cooling tower fan for In accordance with
~ 15 minutes. the Surveillance Frequency Control Program (continued)
GRAND GULF 3.7-3 Amendment No. 120, 201, Page 104 of 162
SSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.7.1.3 Verify each required SSW subsystem manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related systems or components, that Frequency Control is not locked, sealed, or otherwise secured in Program position, is in the correct position. SR 3.7.1.4 Verify each SSW subsystem actuates on an actual In accordance with or simulated initiation signal. the Surveillance Frequency Control Program GRAND GULF 3.7-4 Amendment No. 120, 197, Page 105 of 162
HPCS SWS 3.7.2 3.7 PLANT SYSTEMS 3.7.2 High Pressure Core Spray (HPCS) Service Water System (SWS) LCO 3.7.2 The HPCS SWS shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. HPCS SWS inoperable. A.1 Declare HPCS System Immediately inoperable. SURVE.ILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Verify each required HPCS SWS manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related systems or components, that Frequency Control is not locked, sealed, or otherwise secured in Program position, is in the correct position. SR 3.7.2.2 Verify the HPCS SWS actuates on an actual or In accordance with simulated initiation signal. the Surveillance Frequency Control Program GRAND GULF 3.7-5 Amendment No. 120, 197, Page 106 of 162
CRFA System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 --------------NOTE--------------- associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when entering not met in MODE 1, or 2. MODE 3. Be in MODE 3. 12 hours D. Required Action and D.1 Place OPERABLE CRFA Immediately associated Completion subsystem in isolation Time of Condition A not mode. met during OPDRVs. OR D.2 Initiate action to suspend Immediately OPDRVs. E. Two CRFA subsystems E.1 --------------NOTE--------------- inoperable in MODE 1, LCO 3.0.4.a is not 2, or 3 for reasons other applicable when entering than Condition B. MODE 3. Be in MODE 3. 12 hours F. Two CRFA subsystems F.1 --------------NOTE--------------- inoperable during LCO 3.0.3 does not apply. OPDRVs. --------------------------------------
\
OR Initiate action to suspend Immediately OPDRVs. One or more CRFA subsystems inoperable due to inoperable CRE boundary during OPDRVs. GRAND GULF 3.7-7 Amendment No. 44§, 178, 201, Page 107 of 162
CRFA System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Operate each CRFA subsystem for ~ 15 continuous In accordance with minutes. the Surveillance Frequency Control Program SR 3.7.3.2 Perform required CRFA filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.3.3 Verify each CRFA subsystem actuates on an actual In accordance with or simulated initiation signal. the Surveillance Frequency Control Program SR 3.7.3.4 Perform required CRE unfiltered air inleakage testing In accordance with in accordance with the Control Room Envelope the Control Room Habitability Program. Envelope Habitability Program GRAND GULF 3.7-8 Amendment No. 4-78, 497, 204-, 200, Page 108 of 162
Control Room AC System 3.7.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Initiate action to suspend Immediately associated Completion OPDRVs. Time of Condition B not met during OPDRVs. SURVEILLANCE REQUIREMENTS SURVEILLANCE_ FREQUENCY SR 3.7.4.1 Verify each control room AC subsystem has the In accordance with capability to remove the assumed heat load. the Surveillance Frequency Control Program GRAND GULF 3.7-11 Amendment No. 14 5, 197, Page 109 of 162
Main Condenser Offgas 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify the gross gamma activity rate of the noble Once within gases is s 380 mCi/second after decay of 30 4 hours after a minutes. ~ 50% increase in the nominal steady state fission gas release rate after
. factoring out increases due to changes in THERMAL ,
POWER level SR 3.7.5.2 -------------------------------NO TE---------------------------- .-- Not required to be performed until 31 days after any SJAE in operation. Verify the gross gamma activity rate of the noble In accordance with gases is s 380 mCi/second after decay of 30 the Surveillance minutes. Frequency Control Program GRAND GULF 3 ..7-13 Amendment No. ~ , Page 110 of 162
Fuel Pool Water Level 3.7.6 3.7 PLANT SYSTEMS
- 3. 7 .6 Fuel Pool Water Level LCO 3.7.6 The fuel pool water level shall be~ 23 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool and upper containment fuel storage pool racks.
APPLICABILITY: During movement of irradiated fuel assemblies in the associated fuel storage pool.
- ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel pool water level not A.1 ---------------NOTE--------------'
within limit. LCO 3.0.3 is not applicable. Suspend movement of Immediately irradiated fuel assemblies in the associated fuel storage pool(s). SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the fuel pool water level is ~ 23 ft over the top In accordance with of irradiated fuel assemblies seated in the storage the Surveillance racks. Frequency Control Program GRAND GULF 3.7-14 Amendment No. ~ ' Page 111 of 162
Main Turbine Bypass System 3.7.7 3.7 PLANT SYSTEMS
- 3. 7. 7 Main Turbine Bypass System LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE with two Main Turbine Bypass Valves.
The following limits are made applicable:
- a. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR; and
- b. LCO 3.2.3, "LINEAR HEAT GENERATION RATE (LHGR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR.
APPLICABILITY: THERMAL POWER ~ 70% RTP ACTION CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the requirements of 2 hours LCO nqt met. the LCO. B. Required Action and 8.1 . Reduce THERMAL POWER 4 hours associated Completion to< 70% RTP. Time not met. GRAND GULF 3.7-15 Amendment No. 494, Page 112 of 162
Main Turbine Bypass System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify one complete cycle of each main turbine bypass In accordance valve. with the Surveillance Frequency Control Program SR 3.7.7.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.7-16 Amendment No. Page 113 of 162
AC Sources--'--Operating 3.8.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. Three or more required H.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 power In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 ------------------------------NOT ES-------------------------------
- 1. Performance of SR 3.8.1.21 satisfies this SR.
- 2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
- 3. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.21 must be met.
Verify each DG starts from standby conditions and In accordance with achieves steady state voltage ~ 37 44 V and s 4576 V the Surveillance and frequency~ 58.8 Hz ands 61.2 Hz. Frequency Control Program (continued) GRAND GULF 3.8-5 Amendment No. ~ ' 182, Page 114 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------------NOTES-------------------------------
- 1. DG loadings may include gradual loading as recommended by the manufacturer.
- 2. Momentary transients outside the load range do not invalidate this test.
- 3. This Surveillance shall be conducted on only one DG at a time.
- 4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.21.
Verify each DG operates for ~ 60 minutes at a load In accordance with
~ 5450 kW ands 5740 kW for DG 11 and DG 12, and the Surveillance
~ 3300 kW for DG 13. Frequency Control Program SR 3.8.1.4 Verify each DG day tank contains ~ 220 gal of fuel oil. In accordance with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each In accordance with day tank. the Surveillance Frequency Control Program r SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from the storage tank to the Surveillance the day tank. Frequency Control Program SR 3.8.1.7 Verify the load shedding and sequencing panels In accordance with respond within design criteria. the Surveillance Frequency Control Program (continued)
GRAND GULF 3.8-6 Amendment No. 4-34, 182, Page 115 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.8 -------------------------------NOTE-------------------------------- Th is Surveillance shall not be performed in MODE 1 and 2. However, credit may be taken for unplanned events that satisfy this SR. Verify manual transfer of unit power supply from the In accordance with normal offsite circuit to required alternate offsite the Surveillance circuit. Frequency Control Program SR 3.8.1.9 ----------------------* -------NOT ES-------------------------------
- 1. 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 factors 0.9 for DG 11 and DG 13 and s 0.89 for DG 12. 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 In accordance with its associated single largest post accident load and the Surveillance engine speed is maintained less than nominal plus Frequency Control 75% of the difference between nominal speed and Program the overspeed setpoint or 15% above nominal, whichever is lower. (continued) GRAND GULF 3.8-7 Amendment No. 4e9, 497, Page 116 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.10 -------------------------------NO TE--------------------------------
- 1. 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 s 0.9 for DG 11 and DG 13 s 0.89 for DG 12.
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 does not trip and voltage is In accordance with maintained s 5000 V during and following a load the Surveillance rejection of a load ~ 5450 kW and s 5740 kW for DG Frequency Control 11 and DG 12 and~ 3300 kW for DG 13. Program (continued) GRAND GULF 3.8-8 Amendment No. 4e9, 497, Page 117 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.11 ------------------------------NOT ES-------------------------------
- 1. All DG starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (Not Applicable to DG 13).
However, credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated loss of offsite power In accordance with signal: the Surveillance Frequency Control
- a. De-energization of emergency buses; Program
- b. Load shedding from emergency buses for Divisions 1 and 2; and
\
- c. DG auto-starts from standby condition and:
- 1. energizes permanently connected loads in s 10 seconds,
- 2. energizes auto-connected shutdown loads,
- 3. maintains steady state voltage 2: 3744 V ands 4576 V,
. /
- 4. maintains steady state frequency 2: 58.8 Hz ands 61.2 Hz, and
- 5. supplies permanently connected and auto-connected shutdown loads for 2: 5 minutes.
(continued) GRAND GULF 3.8-9 Amendment No. 4§§., 497, Page 118 of 162
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 be performed in MODE 1,or 2 (Not Applicable to DG 13).
However, credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Emergency Core In accordance with Cooling System (ECCS) initiation signal each DG the Surveillance auto-starts from standby condition and: Frequency Control Program
- a. In s 10 seconds after auto-start and during tests, achieve voltage ~ 3744 V and frequency
~ 58.8 Hz;
- b. Achieves steady state voltage ~ 37 44 V and s 4576 V and frequency~ 58.8 Hz ands 61.2 Hz;
- c. Operates for ~ 5 mi,nutes; and
- d. Emergency loads are auto-connected to the offsite power system.
(continued) GRAND GULF 3.8-10 Amendment No. 4ae, 497, Page 119 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.13 -------------------------------NOTE-------------------------------- C red it may be taken for unplanned events that satisfy this SR. Verify each DG's non-critical automatic trips are In accordance with bypassed on an actual or simulated ECCS initiation the Surveillance signal. Frequency Control Program (continued) GRAND GULF 3.8-11 Amendment No. 4e9, 4-97, Page 120 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.14 -------------------------------NOTES------------------------------
- 1. Momentary transients outside the load and power factor ranges do not invalidate this test.
- 2. Credit may be taken for unplanned events that satisfy this SR.
- 3. If performed with the DG synchronized with offsite power, it shall be performed at a power factors 0.9 for DG 11 and DG 13 and s 0.89 for DG 12. However, if grid conditions do not permit, the power factor lim'it 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 operates for ~ 24 hours: In accordance with the Surveillance
- a. For DG 11 and DG 12 loaded ~ 5450 kW and Frequency Control s 5740 kW; and Program
- b. For DG 13:
- 1. For~ 2 hours loaded~ 3630 kW, and
- 2. For the remaining hours of the test loaded
~ 3300 kW.
(continued) GRAND GULF 3.8-12 Amendment No. 4SQ., 4-97, Page 121 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.15 -------------------------------NOT ES------------------------------
- 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG' has operated ~ 1 hour or until operating temperatures stabilized loaded*~ 5450 kW and s 5740 kW for DG 11 and DG 12, and
~ 3300 kW for DG 13.
Momentary transients outside of the load range do not invalidate this test.
- 2. All DG starts may be preceded by an engine
( prelube period. Verify each DG starts and achieves: In accordance with the Surveillance
- a. in s 10 seconds, voltage ~ 37 44 V and Frequency Control frequency~ 58.8 Hz; and Program
- b. steady state voltage ~ 3744 V and s 4576 V and frequency~ 58.8 Hz and s 61.2 Hz.
(continued) GRAND GULF 3.8-13 Amendment No. ~ , 497, Page 122 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.16 -------------------------------NO TE--------------------------- . --- Th is Surveillance shall not be performed in MODE 1, 2, or 3 (Not Applicable to DG 13). However, credit may be taken for unplanned events that satisfy this SR. Verify each DG: In accordance with the Surveillance
- a. Synchronizes with offsite power source while Frequency Control loaded with emergency loads upon a simulated Program restoration of offsite power;
- b. Transfers loads to offsite power source; and
- c. Returns to ready-to-load operation.
(continued)
)
GRAND GULF 3.8-13a Amendment No. 4-aa, 4-9+, Page 123 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.17 -------------------------------NOTE-------------------------------- C red it may be taken for unplanned events that satisfy this SR. Verify, with a DG operating in test mode and In accordance with connected to its bus, an actual or simulated ECCS the Surveillance
. initiation signal overrides the test mode by: Frequency Control Program
- a. Returning DG to ready-to-load operation; and I
- b. Automatically energizing the emergency loads from offsite power.
SR 3.8.1.18 -------------------------------NOTE------------------------------- Th is Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. Verify interval between each sequenced load block is In accordance with within +/- 10% of design interval for each automatic the Surveillance load sequencer. Frequency Control Program (continued) GRAND GULF 3.8-14 Amendment No. 4ad, 497, Page 124 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.19 ------------------------------NOT ES------------------------------
- 1. All DG starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not be performed in MODE 1, _2, or 3 (Not Applicable to DG 13) ..
However, credit may be taken for unplanned events that satisfy this SR. Verify, on an actual or simulated loss of offsite power In accordance with signal in conjunction with an actual or simulated the Surveillance ECCS initiation signal: Frequency Control Program
- a. De-energization of emergency buses;
- b. Load shedding from emergency buses for Divisions 1 and 2; and
- c. DG auto-starts from standby condition and:
- 1. energizes permanently connected loads in s 10 seconds,
- 2. energizes auto-connected emergency loads,
- 3. achieves steady state voltage~ 3744 V ands 4576 V,
- 4. achieves steady state frequency ~ 58.8 Hz ands 61.2 Hz, and
- 5. supplies permanently connected and auto-connected emergency loads for
~ 5 minutes.
(continued) GRAND GULF 3.8-15 Amendment No. 4-aa, 4-97, Page 125 of 162
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.20 ------------------------ .------NOTE------------------------------- AII DG starts may be preceded by an engine prelube period. Verify, when started simultaneously from standby In accordance with condition, each DG achieves: the Surveillance Frequency Control
- a. in s 10 seconds, voltage ~ 3744 V and Program.
frequency ~ 58.8 Hz; and
- b. steady state voltage ~ 37 44 V and s 4576 V and frequency~ 58.8 Hz ands 61.2 Hz.
SR 3.8.1.21 -------------------------------NOTE------------------------------- AII DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. Verify each DG starts from standby conditions and In accordance with achieves: the Surveillance Frequency Control
- a. in s 10 seconds, voltage ~ 3744 V and Program frequency~ 58.8 Hz; and
- b. steady state voltage ~ 37 44 V and s 4576 V and frequency~ 58.8 Hz and s 61.2 Hz.
GRAND GULF 3.8-16 Amendment No. ~ , 482-, Next page is 3.8-18 Page 126 of 162
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel 6il storage tank contains: In accordance with the Surveillance
- a. ~ 68,744 gal of fuel for DGs 11 and 12; and Frequency Control Program
- b. ~ 44,616 gal of fuel for DG 13.
SR 3.8.3.2 Verify lube oil inventory is: In accordance with the Surveillance
- a. ~ 410 gal for DGs 11 and 12; and Frequency Control Program
- b. ~ 202 gal for DG 13.
SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is: In accordance with the Surveillance
- a. ~ 160 psig for DGs 11 and 12; and Frequency Control Program
- b. ~ 175 psig for DG 13.
- SR 3.8.3.5 Check for and remove accumulated water from each In accordance with fuel oil storage tank. the Surveillance Frequency Control Program (continued)
GRAND GULF 3.8-24 Amendment No. 447, 449, Nexf page is 3.8-26 Page 127 of 162
DC Sources-Operating 3.8.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 --------------NOTE------------- associated Completion LCO 3.0.4.a is not Time for Division 1 or 2 applicable when entering DC electrical power MODE3. subsystem for condition ----------------------------------- A, B, or C not met. Be 1n MODE 3. 12 hours E. Division 3 DC electrical E.1 Declare High Pressure Immediately power subsystem Core Spray System inoperable for reasons inoperable. other than Condition A. F. Required Action and F.1 Be in MODE 3.
- 12 hours associated Completion Time for Division 3 DC AND electrical power subsystem for Condition F.2 Be in MODE 4. 36 hours A, B or E not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is ~ 129 V on float In accordance with charge. the Surveillance Frequency Control Program (continued) ( GRAND GULF 3.8-27 Amendment No. 420, 2G4, Page 128 of 162
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.4.2 Verify no visible corrosion at battery terminals and In accordance with connectors. the Surveillance Frequency Control Program Verify battery connection resistance is s 1.5 E-4 ohm for inter-cell connections, s 1.5 E-4 ohm for inter-rack connections, s 1.5 E-4 ohm for inter-tier connections, and s 1.5 E-4 ohm for terminal connections. SR 3.8.4.3 Verify battery cells, cell plates, and racks show no In accordance with visual indication of physical damage or abnormal the Surveillance deterioration that could degrade battery performance. Frequency Control Program SR 3.8.4.4 Remove visible corrosion and verify battery cell to In accordance with cell and terminal connections are coated with anti- the Surveillance corrosion material. Frequency Control Program SR 3.8.4.5 Verify battery connection resistance is s 1.5 E-4 ohm In accordance with for inter-cell connections, s 1.5 E-4 ohm for inter;.rack the Surveillance connections, s 1.5 E-4 ohm for inter-tier connections, Frequency Control and s 1.5 E-4 ohm for terminal connections. Program SR 3.8.4.6 Verify each Division 1 and 2 required battery charger In accordance with supplies ~ 400 amps at~ 125 V for~ 10 hours; and the Surveillance the Division 3 battery charger supplies ~ 50 amps at Frequency Control
~ 125 V for~ 4 hours. Program (continued)
GRAND GULF 3.8-28 Amendmrnt No. 442, 49-7, Page 129 of 162
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.4.7 -------------------------------NOT ES------------------------------
- 1. SR 3.8.4.8 may be performed in lieu of SR 3.8.4. 7 once per 60 months.
- 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3).
However, credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required the Surveillance emergency loads for the design duty cycle when Frequency Control subjected to a battery service test. Program (continued) GRAND GULF 3.8-29 Amendment No. 4-aQ., 497, Page 130 of 162
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.4.8 -------------------------------NOTE------------------------------- T his Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3). However, credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is ~ 80% of the manufacturer's In accordance with rating when subjected to a performance discharge the Surveillance test. Frequency Control Program 12 months when battery shows degradation, or has reached 85% of the expected life with capacity< 100% of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity
~ 100% of manufacturer's rating GRAND GULF 3.8-30 Amendment No. ~ , 4-a-9, Page 131 of 162
Battery Cell Parameters 3.8.6 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. Time of Condition A not met. One or more batteries with average electrolyte temperature of the representative cells
< 60°F.
One or more batteries with one or more battery cell parameters not within Table 3.8.6-1 Category C limits. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category A limits. the Surveillance Frequency Control Program (continued) GRAND GULF 3.8-35 Amendment No. 420, 442:, Page 132 of 162
Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category B limits. the Surveillance Frequency Control Program Once within 72 hours after battery overcharge
> 150V SR 3.8.6.3 Verify average electrolyte temperature of In accordance with representative cells is~ 60°F. the Surveillance Frequency Control Program
\
GRAND GULF 3.8-36 Amendment No. ~ ' Page 133 of 162
Distribution Systems-Operating 3.8.7 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME
- c. Required Action and C.1 -------------NOTE--------------
associated Completion LCO 3.0.4.a is not Time of Condition A applicable when entering or B not met. MODE 3. Be in MODE 3. 12 hours D. One or more Division 3
"\
D.1 Declare High Pressure Immediately AC or DC electrical Core Spray System power distribution inoperable. subsystems inoperable. E. Two or more divisions E.1 Enter LCO 3.0.3. Immediately with inoperable distribution subsystems that result in a loss of function. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and voltage to In.accordance with required AC and DC electrical power distribution the Surveillance subsystems. Frequency Control Program GRAND GULF 3.8-39 Amendment No. ~ , ~ , Page 134 of 162
Distribution Systems-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to suspend Immediately operations with a potential for draining the reactor vessel. AND A.2.4 Initiate actions to restore Immediately required AC and DC electrical power distribution subsystems to OPERABLE status. AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct breaker alignments and voltage to In accordance with required AC and DC electrical power distribution the Surveillance subsystems. Frequency Control Program GRAND GULF 3.8-41 Amendment No. 420, Page 135 of 162
Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of In accordance with the following required refueling equipment interlock the Surveillance inputs: Frequency Control Program
- a. All-rods-in,
- b. Refuel platform position, and
- c. Refuel platform main hoist, fuel loaded.
GRAND GULF 3.9-1a Amendment No. 120, 138, Correction letter dated 6 18 1999 Page 136 of 162
Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock
- LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.
APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one- rod- A.1 Suspend control rod Immediately out interlock inoperable. withdrawal. A.2 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel position. In accordance with the Surveillance , Frequency Control Program (continued) GRAND GULF 3.9-2 Amendment No. ~ , Page 137 of 162
Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.9.2.2 ------------------------------NOTE-------------------------------
- Not required to be performed until 1 hour after any control rod is withdrawn.
Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.9-3 Amendment No. 420, Page 138 of 162
Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted. APPLICABILITY: When loading fuel assemblies into the core. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control A.1 Suspend loading fuel Immediately rods not fully inserted. assemblies into the core. SURVEILLANCE REQUIREMENTS
- SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.9-4 Amendment No. ~ ,
Page 139 of 162
Control Rod OPERABILITY - Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY - Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE. APPLICABILITY: MODE 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to fully insert Immediately control rods inoperable. inoperable withdrawn control rods. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 --------------- .--------------NOTE-------------------------------- Not required to be performed until 7 days after the control rod is withdrawn. Insert each withdrawn control rod at least one notch. In accordance with the Surveillance Frequency Control Program SR 3.9.5.2 Verify each withdrawn control rod scram accumulator In accordance with pressure is ~ 1520 psig. the Surveillance Frequency Control Program GRAND GULF 3.9-7 Amendment No. ~ , Page 140 of 162
RPV Water Level - Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel LCO 3.9.6 RPV water level shall be ~ 22 ft 8 inches above the top of the RPV flange. APPLICABILITY: During movement of irradiated fuel assemblies within the RPV. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of Immediately within limit. irradiated fuel assemblies within the RPV. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is ~ 22 ft 8 inches above the In accordance with top of the RPV flange. the Surveillance Frequency Control Program GRAND GULF 3.9-8 Amendment No. ~ , Page 141 of 162
RPV Water Level - New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level - New Fuel or Control Rods LCO 3.9.7 RPV water level shall be~ 23 ft above the top of irradiated fuel assemblies seated within the RPV. APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of new Immediately within limit. fuel assemblies and handling of control rods within the RPV. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify RPV water level is ~ 23 ft above the top of In accordance with irradiated fuel assemblies seated within the RPV. the Surveillance Frequency Control Program GRAND GULF 3.9-9 Amendment No. ~ , Page 142 of 162
RHR - High Water Level 3.9.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME
- 8. (continued) 8.3 Initiate action to restore Immediately one standby gas treatment subsystem to OPERABLE status.
AND 8.4 Initiate action to restore Immediately isolation capability in each required secondary containment penetration flow path not isolated.
- c. No decay heat removal C.1 Verify reactor coolant 1 hour from discovery subsystem in operation. circulation by an alternate of no reactor coolant method. circulation AND Once per 12 hours thereafter AND C.2 Monitor reactor coolant Once per hour temperature.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify orie decay heat removal subsystem is In accordance with operating. the Surveillance Frequency Control Program (continued) GRAND GULF 3.9-11 Amendment No. 120, 202, Page 143 of 162
RHR - High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.9.8.2 Verify required RHR shutdown cooling subsystem In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program GRAND GULF 3.9-11 a Amendment No. Page 144 of 162
RH R - Low Water Level 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Residual He~t Removal (RHR) - Low Water Level LCO 3.9.9 Two decay heat removal subsystems shall be OPERABLE, and one decay heat removal subsystem shall be in operation.
--------------- - ----------------------------NOTE------------------------------- _--------------
The required operating decay heat removal subsystem may not be in operation for up to 2 hours per 8 hour period. APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the water level< 22 ft 8 inches above the top of the RPV flange. ACTIONS
NOTE------------------------------------------------------------
Se pa rate Condition entry is allowed for each decay heat removal subsystem. CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Verify an alternate method 1 hour decay heat removal of decay heat removal is subsystems inoperable. available for each inoperable required decay heat removal subsystem. Once per 24 hours thereafter (continued) GRAND G8LF 3.9-12 Amendment No. 4-2-0, ~ , Page 145 of 162
RHR - Low Water Level 3.9.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR,3.9.9.1 Verify one decay heat removal subsystem is In accordance with ope~~ting. the Surveillance Frequency Control Program. SR 3.9.9.2 Verify RHR shutdown cooling subsystem locations In accordance with susceptible to gas accumulation are sufficiently filled the Surveillance with water. Frequency Control Program GRAND GULF 3.9-14 Amendment No. 120, 202, Page 146 of 162
Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor mode 1 hour switch in the shutdown position. OR A. 3. 2 --------------NOTE------------- Only applicable in
- MODE 5.
Place the reactor mode 1 hour switch in the refuel position. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted in core cells In accordance with containing one or more fuel assemblies. the Surveillance Frequency Control Program SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.10-5 . Amendment No. ~ , Page 147 of 162
Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.3.2 -------------------------------NOTE-------------------------------- Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements. Verify all control rods, other than the control rod being In accordance with withdrawn, in a five by five array centered on the the Surveillance control rod being withdrawn, are disarmed. Frequency Control Program SR 3.10.3.3 Verify all control rods, other than the control rod being In accordance with withdrawn, are fully inserted. the Surveillance Frequency Control Program GRAND GULF 3.10-8 Amendment No. 4-20, Page 148 of 162
Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the B.1 Suspend withdrawal of the Immediately above requirements not control rod and removal of met with the affected associated CRD. control rod not insertable. AND B.2.1 Initiate action to fully insert Immediately all control rods. OR B.2.2 Initiate action to satisfy the ,Immediately requirements of this LCO. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to applicable SRs SR 3.10.4.2 --------------------------------NOTE------------------------------- Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1
- requirements.
Verify all control rods, other than the control rod being In accordance with withdrawn, in a five by five array centered on the the Surveillance control rod being withdrawn, are disarmed. Frequency Control Program (continued) ( GRAND GULF 3.10-11 Amendment No. 4-20, Page 149 of 162
Single Control Rod Withdrawal - Cold Shutdown 3.10.4
~:c:;~* . . :*' ...., .........~.:~.- _.:~,: *.:'" _:e:* . , . .. .' . . '
SURVEIL[ANCE:HEQUIREMENTS *{co.ntinued) .. 0#' . . . . SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the control rod being In accordance with withdrawn, are fully inserted. the Surveillance Frequency Control Program
\
SR 3.10.4.4 -------------------------------NOTE-------------------------------- Not required to be met if SR 3.10.4.1 is satisfied for
- LCO 3.10.4.b.1 requirements.
Verify a control rod withdrawal block is inserted. In accordance with the Surveillance Frequency Control Program GRAND GULF 3.10-12 Amendment No. ~ ' Page 150 of 162
Single CRD Removal-Refueling
. 3.10.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to fully insert Immediately all control rods.
A.2.2 Initiate action to satisfy the Immediately requirements of this LCO. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all controls rods, other than the control rod In accordance with withdrawn for the removal of the associated CRD, are the Surveillance fully in~erted. Frequency Control I Program SR 3.10.5.2 Verify all control rods, other than the control rod In accordance with withdrawn for the removal of the associated CRD, in a the Surveillance five by five array centered on the control rod Frequency Control withdrawn for the removal of the associated CRD, are Program disarmed. SR 3.10.5.3 Verify a control rod withdrawal block is inserted. In accordance with the Surveillance Frequency Control Program (continued) GRAND GULF 3.10-14 Amendment No. ~ , Page 151 of 162
Single CRD Removal-Refueling 3.10.5 . SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1.1.1. According to SR3.1.1.1 SR 3.10.5.5 Verify no CORE ALTERATIONS are in progress. In accordance *with the Surveillance Frequency Control Program GRAND GULF 3.10-15 Amendment No. ~ , Page 152 of 162
Multiple Control Rod Withdrawal-Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Initiate action to fully insert Immediately all control rods in core cells containing one or more fuel assemblies. A.3.2 Initiate action to satisfy the Immediately requirements of this LCO. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 0.6.1 * . Verify the four fuel assemblies are removed from core In accordance with cells associated with each control rod or CRD the Surveillance removed.* Frequency Control Program SR 3.10.6.2 Verify all other control rods in core cells containing In accordance with one or more fuel assemblies ar~ fully inserted. the Surveillance Frequency Control Program SR 3.10.6.3 -------------------------------NOTE-------------------------------- O nIy required to be met during fuel loading. Verify fuel assemblies being loaded are in compliance In accordance with with an approved spiral reload sequence. the Surveillance Frequency Control Program GRAND GULF 3.10-17 Amendment No. 420, Page 153 of 162
SOM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.10.8.2 --------------------------------NOTE------------------------------- Not required to be met if SR 3.10.8.3 satisfied. Perform the MODE 2 applicable SRs for LCO 3.3.2.1, According to the Function 1.b of Table 3.3.2.1-1. applicable SRs SR 3.10.8.3 --------------------------------NOTE------------------------------- Not required to be met if SR 3.10.8.2 satisfied. Verify movement of control rods is in compliance with During control rod the approved control rod sequence for the SOM test movement by a second licensed operator or other qualified member of the technical staff.
- SR 3.10.8.4 Verify no other CORE ALTERATIONS are in. In accordance with progress. the Surveillance Frequency Control Program (continued)
GRAND GULF 3.10-21 Amendment No. 420, Page 154 of 162
SOM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdra"'.lfn overtravel position. control rod is withdrawn to "full out" position Prior to satisfying LCO 3.10.Rc requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure ;?!: 1520 In accordance with psig. the Surveillance Frequency Control Program GRAND GULF 3.10-22 Amendment No. ~ ' Page 155 of 162
Suppression Pool Makeup-MODE 3 3.10.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.9.1 Verify suppression pool temperatures 95°F. In accordance with the Surveillance Frequency Control Program SR 3.10.9.2 Verify reactor steam dome pressure is < 230 psig. In accordance with the Surveillance Frequency Control Program SR 3.10.9.3 Verify level in the upper containment pool and the In accordance with suppression pool to be within limits of the Surveillance Figure 3.10.9-1. Frequency Control Program SR 3.10.9.4 Verify level in the fuel storage and transfer canal In accordance with areas of the upper containment pool are ;;:: 23 ft the Surveillance 3 inches. Frequency Control Program GRAND GULF 3.10-25 Amendment No. 4-a4,
' Page 156 of 162
Programs and Manuals 5.5 5.5 Programs and Manuals *(continued) 5.5.5 Component Cyclic or Transient Limit This program provides controls to track the cyclic and transient occurrences identified on UFSAR Table 3.9-35 to ensure that the reactor vessel is maintained within the design limits. 5.5.6 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.
- a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
- b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.
- c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
(continued) GRAND GULF 5.0-11 Amendment No. 420, 142, ~ , Page 157 of 162
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)
- b. A surveillance program to ensure that the quan'tity of radioactive material contained in any outside temporary tank not including liners for shipping radwaste is s 10 curies, excluding tritium and dissolved or entrained noble gases.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies. 5.5.9 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:
- a. Acceptability of new fuel oil for use prior to addition to storage tanks, and acceptability of stored fuel oil at a frequency in accordance with the Surveillance Frequency Control Program, by determining that the fuel oil has:
- 1. a water and sediment contents within limits, and
- 2. a kinematic viscosity within limits for ASTM 20 fuel oil;
- b. Tota.I particulate concentration of the new fuel is s 2 mg/100 ml when tested in accordance with ASTM D-227 4-70 within 7 days after addition of the new fuel to the storage tank; and
- c. Total particulate concentration of the fuel oil in the storage tanks is s 2 mg/100 ml when tested in accordance with ASTM D-2274-70 at a frequency in accordance with the Surveillance Frequency Control Program.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program testing frequencies. (continued) GRAND GULF 5.0-14 Amendment No. ~ , 4-a+, Page 158 of 162
Programs and Manuals 5.5 5.5 Programs and Manual (continued) 5.5.10 Safety Function Determination Program (SFDP) This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:
- a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;
- b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;
- c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and
- d. Other appropriate limitations and remedial or compensatory actions.
A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:
- a. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or
- b. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or
- c. A required system redundant to support system(s) for the supported systems (a) and (b) above is also inoperable.
The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. (continued) GRAND GULF 5.0-15 Amendment No. 429, Page 159 of 162
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.11 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.
- a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.
- b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:
- 1. A change in the T~ incorporated in the license; or
- 2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.
- c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the UFSAR.
- d. Proposed changes that do not meet the criteria of either Specification 5.5.11.b.1 or Specification 5.5.11.b.2 above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).
- 5.5.12 10 CFR 50, Appendix J, Testing Program This program establishes the leakage rate testing program of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be implemented in accordance with the Safety Evaluation issued by the Office of Nuclear Reactor Regulation dated April 26,* 1995 (GNRl-95/00087) as modified by the Safety Evaluation issued for Amendment No. 135 to the Operating License, except that the next Type A test performed after the October 19, 2008 Type A test shall be performed no later than the plant restart after the End of Cycle 22 Refueling Outage. For Type B and Type C local leakage rate testing, this program shall be in accordance with the guidelines contained in NEI 94-01, Revision 3-A, "Industry Guideline for Implementing Performance-Based Option of 10 CFR Part 50, Appendix J," dated July 2012. Consistent with standard scheduling practices for Technical Specifications required surveillances, intervals for the recommended surveillance frequency for Type A testing may be extended by up to 25 percent of the test interval, not to exceed 15 months. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is 12.1 psig.
(continued) GRAND GULF 5.0-16 Amendment No.4-a+, 4e4, 494, 2Qa, 2Q.Q., ~I Page 160 of 162
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.13 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Fresh Air (CRFA) System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under Design Basis Accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent for the duration of the accident. The program shall include the following elements:
- a. The definition of the CRE and the CRE boundary.
- b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.
- c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003 and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.
- d. Since the CRE is at a neutral pressure during isolation mode, the CRE will be maintained, including the following:
- 1. Plant maintenance activities such as modifications, rework, and preventive maintenance tasks on components that could affect the CRE shall be controlled under fleet, plant and system specific procedures to ensure that the CRE boundary is not degraded by such activities.
- 2. Testing of CRFA system sealing areas shall be performed following maintenance activities (rework and preventative) and periodically to ensure that the areas of negative pressures do not leak bypassing emergency filtration system components.
- 3. Fire damper inspection procedures that require opening of duct panels and doors shall ensure that upon restoration no leakage path exists.
(continued) GRAND GULF 5.0-16a Amendment No. 478, Page 161 of 162
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Control Room Envelope Habitability Program (continued)
- 4. The remainder of ducting components such as plenum access doors, duct access doors (rectangular and round), flex connections (ventglass, etc), plugs, and patches will be maintained per paragraph b.
- 5. An assessment of the CRE Boundary will be conducted at a frequency in accordance with the Surveillance Frequency Control Program. The results of assessing items 1 through 4 shall be trended and used as part of the assessment of the CRE boundary as indicated in paragraph c.
- e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of OBA consequences.
Unfiltered air inleakage limits for hazardous chemica.ls must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.
- f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and assessing the CRE boundary as required by paragraphs c and d, respectively.
GRAND GULF 5.0-16b Amendment No. 478, Page 162 of 162
Attachment 5 to GNR0-2018/00013 Proposed Technical Specification Bases Changes (Information Only) (197 Pages)
Control Rod OPERABILITY B 3.1.3 BASES (continued) SURVEILLANCE SR 3 .1. 3 .1 REQUIREMENTS The position of each control rod must be determined, to ensure adequate information on control rod position is available to the operator for determining control rod OPERABILITY and controlling rod patterns. Control rod position may be determined by the use of OPERABLE position The Surveillance indicators, by moving control rods to a position with an Frequency is OPERABLE indicator, or by the use of other appropriate controlled under the methods. The 24 hour Frequenoy of this ~R is based on Surveillance operating enperienoe related to enpootod ohangos in oontrol rod position and the availability of oontrol rod position Frequency Control indioations in tho oontrol room. Program. SR 3 .1. 3. 2 Deleted SR 3 .1. 3. 3 Control rod insertion capability is demonstrated by inserting each partially or fully withdrawn control rod at least one notch and observing that the control rod moves. The control rod may then be returned to its original position. This ensures the control rod is not stuck and is free to insert on a scram signal. This Surveillance is modified by a Note identifying that the Surveillance is not required to be performed when THERMAL POWER is less than or equal to the actual LPSP of the RPC since the notch insertions may not be compatible with the requirements of BPWS (LCO 3.1.6) and the RPC (LCO 3.3.2.1). This Note also provides a time allowance such that the Surveillance is not required to be performed until the next scheduled control rod testing for control rods of the same class (i.e., fully withdrawn or partially withdrawn). This Note provides this allowance to prevent unnecessary perturbations in reactor The Surveillance operation to perform this testing on a control rod whose Frequency is surveillanc.e class (i.e., fully withdrawn or partially withdrawn) has changed. Partially uithdrmtn oontrol rods controlled under the
- Surveillance pouor roduotion requirGd to allou tho ooRtEol Eod movoJ;BGRt Frequency Control FuEthOEJ;BOEG, thG ~1.day FEoquonoy takGS iRto aGGOURt Program. opGEat~ng oxporiGnoo related to ohangos in CRD porfoEmaRoo.
At any time, if a control rod is immovabl~, a determination of that control rod's trippability (OPERABILITY) must be made and appropriate action taken.
+
(continued) GRAND GULF B 3.1-18 LBDCRQ8QQ2 Page 1 of 197
Control Rod Scram Times B 3.1.4 BASES SURVEILLANCE SR 3.1.4.2 (continued) REQUIREMENTS the tested sample are determined to be "slow." If more than 7.5% of the sample is declared to be "slow" per the criteria in Table 3.1.4-1, additional control rods are tested until this 7.5% criterion (e.g., 7.5% of the entire sample size) is satisfied, or until the total number of "slow" control rods (throughout the core, from all surveillances) exceeds the LCO limit. For planned testing, the control rods selected for the sample should be different for each test. Data from inadvertent scrams should be used whenever possible to avoid unnecessary testing at power, even if the control rods with data were previously tested in a sample. The 7.5% of sample size The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. criteria is intended to align with the 7.5% of the total control rods allowed to have scram times that exceed the 200 day Frequenoy based on operating oxperionoo that has sho\Tn oontrol rod sora:s;i ti:m.os do not signifioantly ohango ouor an operating cyolo. This Frequonoy is also reasonable, based on tho t additional euruoillanoos done on tho CRQs at more frequent intervals in aooordanoo Hith LCO d.l.d and LGO d.1.5, "Control Rod ~or.3.Ill P.oou:m.ulators." SR 3 .1. 4. 3 When work that could affect the scram insertion time is performed on a control rod or the CRD System, testing must be done to demonstrate that each affected control rod retains adequate scram performance over the range of applicable reactor pressures from zero to the maximum permissible pressure. The scram testing must be performed once before declaring the control rod OPERABLE. The required scram time testing must demonstrate that the arfected control rod is still within acceptable limits. The limits for reactor pressures< 950 psig are established based on a high probability of meeting the acceptance criteria at reactor pressures z 950 psig. Limits for z 950 psig are found in Table 3.1.4-1. If testing demonstrates the affected control rod does not meet these limits, but is within the 7 second limit of Table 3.1.4-1 Note 2, the control rod can be declared OPERABLE and "slow." Specific examples of work that could affect the scram times continued) GRAND GULF B 3.1-25 LDC 91991 Page 2 of 197
Control .*Rod*** Scram .. Accumu}at<>r$ B ~.J, .. 5 BASES Act10Ns tLf {~ontfnued) lhat: ail i nsettabl ~ control .rbds; ar~ ;inserted. ancJ tha~ the
- reactor.**isln -a ;condition.that cio~sJ1ot; r:equire:* th~ activg function:(f.*e*. ,. scra,n): _of'the :*~on~rol . rm:ls._: .This Reqlfired
- Action ts mpdiffed*_by a :Note :slating that t.he, Required' *.* ...
Action* 1$ nof.ap,:,.-1 .fi:able i:f; aJ l contro*l_. r9ds assoc.tated with the ingp*erabl tt scram *accumulators, are fully lns'e~ted:;
- since.
the f,µt1~Jf9~* of*t.he c;~ntrril r*o~s* ha~ ibeen; performed.* 1
-----tperiodically s1f 3.:l.5.1 eq~ires thatihe c1cct1111ulat:or, pressure be :checked
. . * .. * * ... . . -. ~*~)::etlsure: adequate. accurnulator pres~sUf<<! :e~tsts to proyide *suffi:.<:Jent ~cram force. The> primary :tndtca~or of accumulator OPERABILITY ts: the accumuJator pressure'. A min:im~m,~ccumulator pre:s.$Ure h: specffied,... be}ow::.whic,h the:
The Surveillance :<:apabJlity :of :the ,,accumulator to :per.form its t~tended. . . . . Frequency is tu*nctio,1 . becornes: degraded . and th.e; :accumulator fs. co.nsidered controlled under the inoperabJe. The mtnimuin a*ccumulator pr~ssqre o.f :)S2(): psig Surveillance Js: well bel9w *th~ expe~ted *:pr~ssµre of .1759.Ps{g (Ref~. :2}. Frequency Control * .peel arthg
- t~e . ac<:umul ator*: frlop~ra~llt Whe11. ttt~* J11.irtim~m Program. press4r~; is not )nai~t~in~d: eri.stirei tfi~t;.sfgr.ii'{ica.nt .* ,.
- e_gr~4<1~t9n, .in s.~ram t1rne$~ doe~~* 11()~: 9¢cµ_r. : J~*~: Z *~~.
F-ret1tte~¢Y has .. ~~ea sh~~~ ta,-b~ ~e.e:e~~~.~le: t_~!;~~§h ~P~ra~tRg e~p~r.iefi~~. aAd t~~e:, .*i.A$a. aE:eeur:;t* is,fJi cattafls .availa.~Je in* t~¢ e~=tf.sl -~~a~.. * *
- REFERE.NPE$
,2.;. UfSAij, :s~¢t.i9n 4;;6*~J.1 (2.s.i~
- 3. UFS!\R, *Se~tl9n s*~ 2.2*.2~3~
*~*.*;;. UfSAR;, .S,~ct.t,i*t l.5l4.l..
GRAND :GULF B '3.1-Jl . Page 3 of 197
Cont r.ol .* Rod. P~itef~ B 3:.1.*6 BASES 8.1. :and. 8.2. {C:<>ol,inue*Q} Withdrawals ha'le._ .Req4tre~ ActJM:_B~):.:fs. *mc,tJ.fffe<J*.py :a . .-_*N9t,e
.that allows. thE! affected: co.ntrol_ *rc,ds. :to l)e: bypa's$ed. ;in :RACS
'in accordance wfth<:SR 3:~;3.Z~l..9: tP:: allow insertton only~
*W'itij nine orrrtore OPERABLE control rods *not. in *cornpii~nce-with; BPW$) the .:teactor m9de s:witc:h* rnuH M place~ irt th~'
shutd~wn p_o:sitton* withJn 1- '.h9ut. **. Wi.Jh .the:: :reac10.r)1<>da** . *~ ... ,.. ., . s~itc:~, l~ *.sh~tP9Wri, .. :th~ **r.~ac1:ot J~:*. $h~t clq~,n,' *;~~~. th~r¢..fohf doe*s_ 11ot: mee.t tlj~ .appJ'fc~bflilY: r~tjiJJl'.'¢:~e.~t~: \gf lhiJ: ~C9t th~-- ;allowed pc,mpletiol'l lime . ot*1 *~our is . .r~~:sQn.abl~ ttr allpw tnsertlon of c.ontrol n>d$ to. res1:Qfe. cqrnpJj:~nce:, 31nd Js appropriate... relat>ive te> *the. lo,,r proba~i:lity- of '.~*.***CRDA ciccurrfn~ with 'the c_ontrot rods:. out .of sequence
- SURVElLLANCt .Sit aj.6. . 1.
R.~QVJR:E~E,~TS* The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. RtfERENCES*. 1. :~E()E..t4tl}l-P-A, . _"Gene.ra.J. ~t~c.tric Standard Applfoation ,~ for Reactor*.Fuel *fGESTAR U)." .. .f'.. UFSJ\~,: *.s~cti911 1s.:f~~-
*N~R~G~9~79\ "NRC :s:afety:EVal4~tipti *B~po,rJ ~~:],'a~e~ tQ*
*tlj*~ Fi'n~'T. ,Q.~sJgJr l\pprqVaJ '9f. :t.~! tgg$SA8 ,Jl; B..WRZ6. .
Nu¢J~a.r lll~nd De~ign*~ .ooe~e:t N.o. &0'-447/' sectto,, 4. 2 .1.3. 2, AprJ.1 1983.
- NµRE~~oao:o*, *.Standard' Revtew Pl-anti.i :sectton l5.4.;9,-
Radi.ologfcal t()n~equences of'.:Coritrol .Rod **orop:
- A¢tld~~r*(BWR};'~ Re.vi$J<>n ?t. J~ly *1:~fHe.. . .
5 *. 1.? C:fR.*. . 100:~::q.,
- D~.t~r111in.a't.f91'1 . Qf ::~,cc::TYstqrt A..t~l,. ~ow' 11 P.opyJiitlorr: ?911~, ai'l.d P6p.tihlton: C'eot~t* Qi$trJ:nt~**" .
(contJnued} GRANP\ GIJLF' *s *3. i.;.3S Page 4 of 197 *
- SLC System B 3.1.7 BASES ACTIONS E.1 (continued )
concurren t with the failure of the controls rods to shut down the reactor. I F.1 If any Required Action and associate d Completio n Time is not met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to MODE 3 within 12 hours. The allowed Completio n Time of 12 hours is reasonabl e, based on operating experienc e, to reach MODE 3 from full power condition s in an orderly manner and without challengin g plant systems. SURVEILLANCE SR 3.1.7.1 and SR 3.1.7.2 REQUIREMENTS SR 3.1.7.1 and SR 3.1.7.2 are 24 heur £urvoillan oos, verify~ certain character istics of the SLC System (e.g., the volume and temperatu re of the borated solution in the storage tank), thereby ensuring the SLC System OPERABILITY without disturbin g normal plant operation . These surveillan ces ensure the proper borated solution and temperatu re, including the temperatu re of the pump suction piping, are maintaine d. Maintaini ng a minimum specified borated solution temperatu re is important to ensuring that the boron remains in solution and does not precipita te out in the storage tank or in the pump suction piping. The Surveillance Maintaini ng the temperatu re less than 150°F ensures Frequencies are pump net positive suction head requireme nts for two controlled under the peration and SLC System piping qualifica tions. ""'"T+h~e----"r"" Surveillance Frequency Control Program. (continued ) GRAND GULF B 3.1-40 UlQCR 1QQ3a Page 5 of 197
SLC. sys:f¢rri'
. B J/1.7
*SURVEILLANCE :SR 3 ~L7.3 *ah'd SR '3\1.7 .. 5 REQUIREMENTS:
The. .requi*rements of dp CfR: .50}6Z. ar~ met Jw the O$ff d.t. :a . so*dtum p~ntaborate solution *enrfc:fled. in.* the: ijo.ron:~to {B~to) isotope .. SR. 3.-1.]! 3 det~rmine_s whether, th~ sodium pent~i:>.ora:t:e \cpnpen.tra1:i;on.,. :; n_*.:cortJllm:::t;tcm** wH.h th.e 1:>or911
- en riqhme11t, . i 5i_ wf~M n* lirniJ?: t9 *.rne~t <the re9Htrem.~_11~s-- <>..f ).O:
- cfR<s:Q.62\ SB; 3~1.'7:.s enst1res th~i :'th~ para.rne_t:~r~; µs~d.: 111.
**t~~- q.e1;er111fn<J.tioo_ ;of_._.sqdiLJiT1_.* p~nJabor~j:e. _ c:9nc~ntf~tion w*, thi ri i:+mits. The. civailabl ~ $()]litio'n :v9l'ume is -t~e*s'olu1:iBn
~r~;
!iij1!'!~i~i!:~~;il~i~[z~:ff!~~:!i;t~~]iii~t!i?it!~ii!filJR:~
- t9 exist?' +n the storage tank* SR 3~1-/7~5 ;must '.be *per-f9rmed any-time .:boron or wa~er +s,. a:ddecJ 1:cr th¢ ,storage tank solt1t-1,on tP'¢stablish tl;,at **the./weight of*.s~10. :,~ Wfthin the spedf.i*ed.
- ii'tnlts. This SRmust b¢ perfC>".'l'.flt:!q ar,ytime 'thec:spltJ;tj()r,_
The time interval temperaturf*ts r~stored fo. ~ 45-~f, to :en*~ure no :s,*gnif,cant ~ based Surveillance boron prec1:p1tat1on :occi:.irred. Frequencies are controlled under the The )i; cla:,. Freet~~~~Y e.f 1:hese ~.S.tJfveHl.~flegs i~ ~~19~.a~r=ia;t:e' Surveillance ~.eee.tas e ef :t:fre t~Ja.1ci *orely ..s}:t1*.~ ~*a.ri.$.~J ~-~ af. ~) P~A Frequency Control *_c9a¢e~*tr~i:o:fl betweefi si:t)"vei]J~f.lees.
- Program.
SR .'3*-~La ...4 iai,d SR 3.L 7.6.
'SR 3.L?.4; Ver{fies .,the -*contiiildty'. of th~. ei<plosi\ie_.Will chatges in the, injectionva.1Ves to. ensure *proper operation *
- c>(:ct.it {f reqtii red.. *
{continued) GRAND ' GU.CF Page 6 of 197
SU.RVEILLANCE REQUIR:E~~NJS The Surveillance Frequency is i!t;l:.f!~~w~:;¥==~** ~.~l~~~nit~.*. =~¢~~'~*~*~~~:*ti,ti~~:P,~~~ controlled under the 5=.R ..3.:.1L7\l>V~fif"i:e$ ~a.th. *-valyf! y, _.th.ij.'$y~ft~ni is fr{ its< Surveillance Frequency Control !~jqf :M:si1~e:f,*.~~ee$~,~i*~iti~tPlt;;il!1f~~fu~~~j:i'S{~&? m~nual; .. powe:r_ C)p~rate.d,. and *a.utomatic valves i tj ~he Program. Sys:tem\flow. :~ath ensures that. the pr-aper* flow paths .. wi 11
.exJst_ to:~ sy5tern Op(H~ati'on. A*val:'Je_l~ .*al s*~'*ctlJowecJ._to. ~e*
tn-'the *,:ronaccident': poifitfoh, . prO.vided. i't can*, be i~l igned to the _accident .position from the< ton:trcfl .._._room;. or lotall}' by a. d*edh:ated operator *at t~e. valve '('.Ontrols~ . Th-ts is'.__ _*_ *.
*accep,ta.ble>since, .th~>.SLC:.System .* ; s a>*manually in.itiated
,system;. This* :surve.iJlance *_does. not applY ,to' vatves :that ~re.
fo(tl(eci, S.eai~cl~. ,Ol'.Oth~rWi.$E! S~~uretf. i'n iP,OS"ltlQO, ~lnc~. they
~e*re veri fi(ed to :be in the c:<>.rre~:t: posftfon priqr :tQ; . . . .
Tof~ing, $~aljng, _ o-r s~curil"lg .. _Thi$. ve:r-1ffcat.ton of valve
~}i;g11rn~n~ *~qes: l')Q~L~PPl y 1:Q yaJ.v~.S. 1;h~t cc1n,r.1Qt*. };)e . . .. .. .
jnac:lv,E!rtt?nt]Y* misa1*:;:g11~d~ :S~Ch'1..S ch~c~ v~ly~~-. 'This $Rf. The Surveillance d6e.~. not: r~qu{re *. a~y._.1:estj11g* or. valv~ ;manJ plll a~j on; :rat.n~*r, Frequency is it: inv~lv~.~:v~_riJi,~atJonFh~~*1:1,9~~ vaJv*~~: iap~blg qf ~~1119 controlled under the m;*spos{til)ned ar*¢* tn: the corr~ct, po~it.igris~*... The3.l day*<*** Surveillance Frequency Control Program.
~!~::e~te!!:!~!!~i:~ir~}!:!~e?~~m~~iV~"~~~MW~~i~~~~
(continued} Cr<AND .GULF Page 7 of 197
SLC System B 3.1.7 BASES SURVEILLANCE SR 3 .1. 7. 7 REQUIREMENTS (continued) Demonstrating each SLC System pump develops a flow rate 3 41.2 gpm at a discharge pressure 2 1370 psig without actuating the pump's relief valve ensures that pump performance has not degraded during the fuel cycle. This minimum pump flow rate requirement ensures that, when combined with the sodium pentaborate solution concentration requirements, the rate of negative reactivity insertion from the SLC System will adequately compensate for the positive reactivity effects encountered during power reduction, cooldown of the moderator, and xenon decay. This test confirms one point on the pump design curve, and is indicative of overall performance. Such irtservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this Surveillance is in accordance with the INSERVICE TESTING PROGRAM. ~ SR 3 .1. 7. 8 This Surveillance ensures that there is a functioning flow path from the boron solution storage tank to the RPV, including the firing of an explosive valve. The replacement charge for the explosive valve shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of that batch successfully fired. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. Tho pump and o.xplosivo valve tostod should be alternated such that both complete flotr paths are tooted ovary 4g months, at alternatin~ 24 ffionth intervals. The Surveillance may be performed in separate steps to prevent injecting b9ron into the RPV. An The Surveillance acceptable method for verifying flow from the pump to the Frequency is RPV is to pump demineralized water from a test tank through controlled under the one SLC subsystem and into the RPV. Tho 24 month Frequonoy Surveillance is. basod on tho nood to porforHJ this ~hir:uoillanoo under tho oonditions that apply during a plant outage and tho Frequency Control potontial for an unplannod transiont if tho guiveillance Program. r.roro po.tforHJod uith tho roactor at pouer. Operating Ern;periGnee has shoun thosG eoHipononts Hsually pass tho gurvoillaneo toot uhon porformed at tho 24 Hmnth Frequency; thoroforo, tho Frequoncy was conolHded to be aoeeptable, from :i reliability standpoint.
- continued)
GRAND GULF B 3.1-43 LBDCR l§g1g Page 8 of 197
shV Vent :a:nd . Dr'ai'n
.. . 8ValVe'S
'3.i~,a
- ACTlQN'S,.
Ti:me .6t 12 h.ou.rs1 is teas:ctnable, .b:a.s!e~'. on b:p;~:rattnQ . .
'eXperience:; :tcr "i'~,ecrch* MODE :3\ from* 'futi p'ower* :condJt:;:.ons rn an:
gf4~rJi: r@hh¢/* ajtcf W.ithi:>ul ¢.h9JJ ertg:ittf :pJ~)\t.* ~Y:#leMs.
*sukVt&LtANct
*.Rs9UlREMENTS o:uff11g., Fl9trnfl RP.gra"t,iJ?tr, *th_e* $:PY. \ ~Dt ~,rt~L ;cfo~fn V~Jvt¥*~
1 sh:q9JA p.e J n. to~ pp.en p-o:~jtj.Qn ..(~:xogp{.:when, .-P~f.f'prm,tng
.Sit *3'.::r.s* .. 21 to* aJ low tor dra+rtage*. or-the sot plpJng .:
The Surveillance Frequency is
.m;:i~ri!~:Ii~; i~f:1::~!::ft;V!i~~!i!,:~;~itif:~~i*t::snQ}
0 requ.i:re. :any :teit:i:n*~r o.r va'Jte marf{pulat:+o:n; raiher*~-.. **it controlled under the Surveillance Frequency Control
- Ptogr~m; *
- J~,~~:1!~,:~!Bf:~!:~,!f:stm,af~.tn~:: ~! ,:lz: ~*~i~ml~t
;$e~*e-e:ryt~~r. v;al*vc :el:'etat:~'erf, \~~, ck', ;efl!H.t~e* e:erte,?~-. ..ra'lVi~ .
1
-~esi:tiei--t:s.. Irnprcrpcfr* **val~e:* p~~siti:oh: ftlOs:edJ would :not, 1
~ffe¢t; the.* l$9}afion fuhc{i'.;c>n.-~
The Surveillance Frequency is i~r,~~~t!t~~,ih:;* r!~:t!:\:{;{,. j{~i~:;;[;/{!.vf~~§~bt*!i~J~!;** C/clhi9, :erat:h valve **thr.bUQh. :;ts, *compff':ete: t:ange of mdt:fon
- controlled under the Surveillance Frequency Control m~~~1/d~pi*~~rt ~*~*a.fHf Ofl,e_f?t.ll'rl'§ '$)rn,i:r:.ij:'eR~e
~~t. * ¥~~\~h;~yrm~t~l!,/~~cii~zij t:aJ<e~ lfl=&.E:l t;1pp~*eflt ti=IEr level :rd
. .*~"
Program. i2c-:eia.fiaa.ac;y lr=i t!:l:e:: s.~*stcm* acsf§.rn. t,:T~:~t*~~~~l a s,dmu1at,~d qr f,¥~ iaJ:Jr:~ii~tetlrf
;'agtua'l:* :;cr:am. s}gnal,-.
tr~;~cif v *. ~:;itti!;a,[;t*~f t.he :clJYs:ure,' o.f** the'._ *SDV v:etlt ana* drain valves ;:.s.- verift:ed'.. The *clo*s'.ure ti'tnEt of
~:u~~ti~dMI!J! :tart!lf fulle~: . i~f!Wll[mlle.~i Stmi larly,, after r~ceJpt of: a .simulatecl *or acttia*l ::scram:
- !!i~~f ,i. 1 ije cc*oHtfriUe d):
Page 9 of 197
SDV Vent and Drain Valves B 3.1.8 BASES SURVEILLANCE SR 3.1.8.3 (continued) REQUIREMENTS reset signal, the opening of the SDV vent and drain valves is verified. The LOGIC SYSTEM FUNCTIONAL TEST in \
\
LCO 3.3.1.1 and the scram time testing of control rods in The Surveillance LCO j.1.3, "Control Rod OPERABILITY," overlap this Frequency is Surveillance to provide complete testing of the assumed controlled under the safety function. Tho 24 :month Froq1,1onoy is based on the neod to perform this gyproillanoe 1,1nder tho oonditions that Surveillance apply during a plant outage and tho potential for an Frequency Control unplanned transient if tho eurueillanoo uero performed uith Program. tho reaotor at pouor. Oporatin~ 01r,perionoo has ohmm those oompononts us1,1ally pass tho e1,1rrroillanoo uhon performed at tho 24 Hlonth Froq1,1onoy; therefore, tho Froquonoy uas i-oonoludod to bo aoooptablo from a roliability standpoint,
, REFERENCES 1. UFSAR, Section 4.6.1.1.2.4.2.6.
- 2. 10 CFR 50.67, AAccident Source Terms.@
- 3. NUREG-0803, "Generic Safety Evaluation Report Regarding Integrity of BWR Scram System Piping,"
August 1981.
/
GRAND GULF B 3.1-49 LDDCR 13943 Page 10 of 197
. . . . . . . . . . ______.;.;._~-"'4.-------------------__.,....----...........i* The time interval based
- qH~l:>fffrl :4\ Surveillance Frequency is
--------------1controlled under the l::,_, D'fsAR,*, fchapt:er is., -.A.p-~entil.>t .iscL- Surveillance Frequency Control Program.
t~,: Qif&~Bli ~h~Pt~r J.t; )~PP.~m<J;t,),(:, :i5:rt, A,, . :;i[i~l!t!If;;t}J!t~i?i;:g~i!~!!!?i::!!!~i!~~,irr~t~,:Qn
~ffi!!!tif![;.;; f~!~gi~J,1~t~tdiWM~,~N1i~i~1!~::r i?:?rr~ 0
*A "Ne -* **
- J El * - * ****-* ::stanaafd\:Ap*,*.--.*_-,_-_P-_. -1,_.*.ca_* *:arr
,* &1:of ~:~ct~:t.**e' :#di' fb.*r'*i'.k24011 :i'*,,.e'~istWr(5*.*-*!{e*ct.rJ,C * **.:i:.*,_*_*,
Page 11 of 197
- t'9.RY$~.~~i~c:~'..
;ijgQP:+R§M~tin~*,
Iperiodically The time interval based Surveillance Frequency is controlled under the Surveillance Frequency Control Program. (f~B~~?g;ff;~ff~fefl~fh;i1lif:}if cSiifao~~rf~ ~!fr>l i'cat'frili UFSAR*: chap*
,.,., ......,.,.-.... ,.,./,.\ ...... ' t e r is 1
- ......... *.i',:,,.,,;*-- .,,;;, ...) "A_\_,
~t:'I. . .*
.. _n
. ._n_._.e d -.:.fl_.-~_.,-_i...x_* ,-_l_* _*_*.
* ._ s.*.s1_'. i Q,F§~Rf{ ~s.ti~Rl~f J%i ~pp~:,;rijj\X2 J$,t}?
Page 12 of 197
tHGR" ij/ ;~:\g\ :3,
'A:;1 :c¢qri(inU~d),
res,tgfe the . . LHGRCs) . *to :wit-h'in . ft~* .retjuJ.red: Tfmj:f(§) ;~u.:<:h:
~Hat: Jh~ pl?ot.* i:s :qperariqg w{.thi,-p ~naJ:yzea ,cgnd;it{?n$** arjd,
':~ttfjin, 1ih.e d~sigpi limtts ,O! ~he. fueJ codsJ. The 2 :hout (2ornpl e.don . -T'rme* :,ts <notrnal ly* svfft(terrt: to. *C~$.tC>f:~. :t:fre L!iGR (~} *t(;LWJ.tbi ~* t1:s* Jtro:i::t, ~~ct. fa:>a.cc~.ptf!lf).~ pa.1~# P?:' ;he
'low ,pr:obabiT].ty; of a' *1:.rarrsJ~ni: :or*DE?sign B.il$j's< J.\t*i;:td¢nt* .....
pgcurrJng' >s1,mu1*tan~()~~lY \vi.th: the'.LHGR: q4(c:* gf ..,s:,:1~:c{f.{qa(io,ff~
;B./1.
If the L.HGirtannot-be* res,t9re~.i to* Wi'thi;'n: +ts. {e91.Jifed }cimlt wtthirj *the as~~<ti:ated (qmpJEi!ti.onJfme, :the** .t>lan*t- mu$'~* :be
- br;pµg,ht: tQ: a ;}1pof PF .9th~r . *spe<:ifi'e:d c::gpd.i1:1,,o:n j:q. wh1*gtr**: .1:h.e
*.~<o d.oe.~ :nQ1: :~pply. 'Tp, ~c.hf~ve*th15; st~t:US; *. :J}l.El{Mtc'PpWJ:*~ .:
!}!i~fftf~::if:r!iu1;t!~i~~Ei~~!iS!i:fl!iitJ!ii:t;J:td ?
s~l&ft4~~ANCE> :SR .. :3':j(3:.:f 'iREQU.IREMENTS.:*
~,r~e~g~~~?,~~f~rrfH~k~At ~~~~:~ ~~)~1~~:~;c~fu~µ~tl~[t~~~~~}~~&. -+-
2~. h~1:1rs try~r~aft¢r~> . Iryey. a::r~***. c9mpar~9* W'J~h . t.1\¢ ,~P%1:faed: TJmi.ts.. ih t~e/'fObK .~<> . *.e'ns~:fg *th.a/ .*t~e::*r~c1C:#9( 'ts: .OJJJ!f"~{i:9Jl
\Vf~hin the ;,assumptions, :df: the safety *ah~l.Ys.+:s;: . . *. Tt:ie 2~: lfotu
n*e~u.ene:y ls' ba:s§cl: :ei, beth: e.FtgJneer=in~ jt:fdg,nen"t'. ,s;,~a, * . ** . *
;f'e.eo9rti ti"en , e.f, 'cli'e:' ~.le~.;, e:ss . ~ff eJ,~l"l~fe3 .J:1'1 ~Bwd'ei'r ei.i.!5 t'rJbtitf6M tl~:aef' l"l(ffffl.al ;~eft~lti.eAS .. Th~ '12* hour ~JJow~mc~: ~f:tf:?f*; .
I,HERMAL POW@.;i ?.J~:s~. RIP is. ?tcb+§v~d. js ,acgepJ~Qfe,,::giy1=n.. .i-j:,h~'. tctr:g~ i'pherent fnc3/gi'n J:q. ope.r;:it;:i'ng 'H;rn}'t:s*: a::~, Jqw~*t: 'PQW~t: i:~veJ$ *.
- 1~ The time interval based Surveillance Frequency is controlled under the 2:.: ;UFSAR} chapter :4.! Surveillance Frequency Control Program.
'3', NQ:REG7.0ijQ6, S:tancfard*:ReVfew. f>]an,if ::s~cti:on: ,4.},,:
<r:r~A~ 2:(g}, 'Reyjs,qn;, 2, Jul,y '.tQBi.
Page 13 of 197
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.1 and SR 3.3.1.1.19 REQUIREMENTS (continued) Performance of the CHANNEL CHECK ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring\ the 1 same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift on one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it.is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.- Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit. The agreement criteria include an expectation of overlap when transitioning between neutron flux instrumentation. The overlap between SRMs and IRMs must be demonstrated 'prior to withdrawing SRMs from the fully inserted position since indication is being transitioned from SRMs to the IRMs. This will ensure that reactor power will not be increased into a neutron flux region without adequate indication. The overlap between IRMs and APRMs is of concern when reducing power into the IRM range. On power increases, the system design will prevent further increases (by initiating a rod block) if adequate overlap is not maintained. Overlap between IRMs and APRMs exists when sufficient IRMs and APRMs concurrently have on-scale readings such that the transition between MODE 1 and MODE 2 can be made without either APRM downscale rod block, or IRM upscale rod block. Overlap between SRMs,and IRMs similarly exists when, prior to withdrawing the SRMs from 'the fully inserted position, IRMs are above 2 I 4 0 on range 1 before SRMs have r'eached the upsc~le rod block.
- If o~erlap for a group of channels is not demon~trated (e.g., IRM/APRM overlap), the reason for the failure of the Survei~lance should be determined and the appropriate channel(s) that are required in the current MODE or condition should be declared inoperable.
The Surveillance Frequencies are The Frequenoy of onoe e:uery 12 hm:1.rs for ~g 3.3.1 l~is based controlled under the upon operating eH.perienoe that demonstrates ohannel failure Surveillance is .rare The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational Frequency Control use of the displays associated with the channels required by Program. the LCO. (continued) GRAND*GULF B 3.3-23c LBDCR 16272 Page 14 of 197
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE Tho Froquonoy of onoo ouory 24 hours for g~ 3.3.1.1.19 is REQUIREMENTS based on improved prooossing and roduood drift of tho 1 ( continued) digital equipment in oo:mbination uith four fully redundant* flou transmitter ohannols and improved failure dotootion (Roforonoo 15), 1 SR 3 . 3 . 1. 1. 2 To ensure that the APRMs are accurately indicating the true core average power, the APRMs are calibrated to the reactor power calculated from a he_at balance. Tho Froquonoy of onoo per 7 days is based on :minor ohangos in LPRM sensitivity, Hhioh oould affoot tho APRH reading botHoon porfor:m.anoos of The Surveillance gP, 3 . 3 . 1. 1. 7 . Frequency is controlled under the A restriction to satisfying this SR when< 21.8% RTP is Surveillance *provided that requires the SR to be met only at~ 21.8% RTP because it is difficult to accurately maintain APRM Frequency Control indication of core THERMAL POWER consistent with a heat Program. balance when< 21.8% RTP. At low power level~, a high degree of accuracy is unnecessary because of the large inherent margin to thermal limits (MCPR and APLHGR). At
~ 21.8% RTP, the Surveillance is required to have been satisfactorily performed coi tlrir'r the las L 7 e.@l.'.} @! in accordance with SR 3.0.2. A Note is provided which allows an increase in THERMAL POWER above 21.8% if t h e ~
Frequency is not met per SR 3.0.2. In this event, the SR* must be performed within 12 hours after reaching or exceeding 21.8% RTP. Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR. SR 3 . 3 . 1. 1. 3 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. As noted, SR 3.3.1.1.3 is not required to be performed when entering MODE 2 from MODE 1 since testing of the MODE 2 required IRM and APRM Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads, or movable links. This allows entry into MODE 2 if t h e ~ Frequency is not met per SR 3.0.2. In this event, the SR must be performed within 12 hours after entering MODE 2 from MODE 1. Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR. (continued) GRAND GULF B 3.3-24 LBDCR 16878 Page 15 of 197
RPS I~strumentation B 3.3.1.1 BASES SURVEILLANCE SR '3.3.1.1.3 (continued) REQUIREMENTS P. Froqt1.onoy of 7 days provides *an aoooptablo level of systoFfl. The Surveillance a:uora1ge availability over tho FroqHonoy interval and is based on reliability analysis (gof~ 9). Frequency is controlled under the Surveillance Frequency Control SR 3 . 3 . 1. 1. 4 Program. A CHANNEL FUNCTIONAL The Surveillance Frequency is controlled under the Roferenoo 9. ~(~T~h~o,-.i",D4~a~n~u~a~1~~,'-d+/-l+--.t'-++/-+/-+/-e-1c=-+/--1:*+-'--o-~~~E!r.l:::r Surveillance FUNCTIOJ?ll'L TgaT Froqt1.enoy uas oroditod in tho analysis to Frequency Control mrtond many aHtmi:iatio sora:m F:fmotions' Froqt1.onoios. ) Program. SR 3.3.1.1.5 and SR 3.3.1.1.6
)
Deleted (continued) GRAND GULF B 3.3-25 LDC 06007 Page 16 of 197
RPS Instrumentation B 3.3.1.1 BASES
- SURVEILLANCE SR 3.3.1.1.7 REQUIREMENTS (continued) LPRM gain settings are determined from the Core power distribution calculated by the Core Performance Monitoring system based on the local flux profiles measured by the The Surveillance Traversing Incore Probe (TIP) System. This establishes the Frequency is relative local flux profile for appropriate repr~sentative controlled under the input to the APRM System. Tho ;;moo D4-v¥D/T (mogauatt Surveillance days/ton) Froql:l.onoy is based on operating oxporionoo Hith LPRM sensitivity ohangos. For the pl:l.rposo of calcl:l.lating Frequency Control this suruoillanoe frequency, tho ton (T) unit of Height is Program. mrprossod in terms of metric tons of Hranimn fl:l.ol residing in tho reactor core.
SR 3.3.1.1.8 and SR 3.3.1.1.11 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the The Surveillance intended function. Any setpoint adjustment shall be Frequencies are consistent with the assumptions of the current plant controlled under the specific setpoint methodology. Tho 92 day FroqHonoy of
~g 3.3.1 1 Q is based on tho reliability analysis of Surveillance Roforenoo 9.
Frequency Control Program. Tho 24 month Froql:l.onoy is based on tho need to perform this~uruoillanoo l:l.nder the oonditions that apply during a plant Ol:l.tago and tho potential for an B.nplanned transient if
-+-
tho ~l:l.ruoillapoo.uoro performed Fith tho reaotor at pouer. Operating experience has sho\Tn that these components usB.ally pass the ~l:l.rveillanoe Hhen performed at tho 24 monthFroql:l.onoy. (continued) GRAND GULF B 3.3-26 LBDCR B04s Page 17 of 197
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.9 REQUIREMENTS (continued) The calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the' trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.1.1-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be The Surveillance readjusted to be equal to or more conservative than Frequency is accounted for in the appropriate setpoint methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.1.1.10, SR 3.3.1.1.12 and SR 3.3.1.1.17 A CHANNEL CALIBRATION is a complete check of the instrument loop and th~ sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology. Note 1 states that neutron detectors are excluded from CHANNEL CALIBRATION because of the difficulty of simulating a meaningful signal. Changes in neutron detector sensitivity are compensated for by performing t h e ~ calorimetric calibration (SR 3.3.1.1.2) and the 2899 HHe'/T LPRM calibration against the TIPs (SR 3.3.1.1.7). A second Note is provided that requires the APRM and IRM SRs to be performed within 12 hours of entering MODE 2 from MODE 1. Testing of the MODE 2 APRM and IRM' Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads or movable links. This Note allows entry into MODE 2 from MODE 1 i~ the associated Frequency is not met per SR 3.0.2. Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR. (continued) GRAND GULF B 3.3-27 LDC 07045 Page 18 of 197
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.10, SR 3.3.1.1.12 and SR 3.3.1.1.17 REQUIREMENTS ( continued) Note 3 to SR 3.3.1.1.10 states that the' APRM recirculation flow transmitters are excluded from CHANNEL CALIBRATION of Function 2.d, Average Power Range Monitor Flow Biased Simulated Thermal Power*- High. Calibration of tho floH transmitters is performed on an 24 month froqHonoy (£g
- 3. 3. 1. 1. 17) ,
SR 3-.3.1.1.10 for the designated function is modified by two notes identified in Table 3.3.1.1-1. The first note requires evaluation of channel performance for the condition where the as-found setting for the.channel setpoint is outside its as-found tolerance but conservative with respect to the Allowable Value. Evaluating channel performance will verify that the channel will continue to behave in accordance with safety analysis assumptions and the channel performance assumptions in the setpoint methodology. The purpose of the assessment is to ensure confidence in channel performance prior to returning the channel to service. Performance of these channels will be evaluated under the Corrective Action Program. Entry into the Corrective Action Program ensures required review and documentation of the condition to establish a reasonable expectation for continued OPERABILITY. The second note requires that the as-left setting for the channel be within the as-left tolerance of the Nominal Trip Setpoint (NTSP). Where a setpoint more conservative than the NTSP issued in the plant surveillance procedures, the as-left and as-found tolerances, as applicable, will be applied to the surveillance procedure setpoint. This will ensure that sufficient margin to the Safety Limit and/or Analytical Limit is maintained. If the as-left channel s~tting cannot be returned to a setting within the as-left tolerance of the NSP, then the channel shall be declared inoperable. The second note also requires the NTSP and the methodologies for calculating the as-left and the as-found tolerances to be in the Technical Requirements Manual Tho Fro~Honoy of 24 months for £g 3 a 1,1 12 and
£g3,3.1.1 17 is based Hpon tho assl:1-Hlption of tho maGnitHdo of oqHipmont drift in tho sotpoint analysis.
(continued) GRAND GULF B 3.3-27a LBDCR 14034 Page 19 of 197
RPS Instrumentation B 3 . .3.l.1 BASES
~
- SR 3,3,1,1,12, and SR 3.3.1.1.17 (continued)
.* Sl)IWEiLLAN~E SR .3
- 3 .1. L 10 it 1' REQUIREMENTS
{continued) Tl=ie Freq1:J:eAty of 24* fflOfltAS for SR 3. 3 .l .1.10 is aasea tlJ90A j1:Jstifi caticm prO\/ided fo .RefereACC lS. The. only analog components involved with main s i gna1 processing *~re jnput isQ:lation amplifiers (one per LPRM and one pef:flow ~fopu"t), a sc1mple-ancl;..hold circuit, and an analog-to.:.djg.ital {A/D} converter. These analog components are'~ighly r~liabl~and very stab 1e with virtua11 y no drift~ In adtjitfon; .the sample-and~hold circuit and AID COOVE!rtersare1:E!Sted :a$* part of the ?-llt()matic self-test. . . The prOcessin*g hardwar.e* for the APRM* Functions* rs* digital and has no drift. one of the 'most sensitive signals~ the: fiow processing' is automatically compared. b~twe*eri charliiels. Any digital failures will be identiffed by the 1aut:Omafi¢* . .
- Self~test, CHANNEL CHECK, or in very rare cases by the CHANNEL FUNCTIONAL TEST.
Theautomati.c self;...test includes steps that check the performance and accuracy of the sample arid hold :c;:i rcuits and I" the A/0 converters, and .the related processing. Self:-test logic. also periodically tests the foput amplifier~ and.. pr.(?cessing -for accuracy. In ~ddition, CHANNEL 'F4NCTIONAL . TESTS include an automated "cal check" which will check :the performance 9f all of the analog amplHiers and the endre t
'-l.
processing loop. t Tfle .¢omb.in(ad improvement*.justifies. the . factor~of-.fqur inc*rease** in calibrafion. interval' part'icularly. in that the cal i bra ti on will actually be checked at* the CHANNEL FUNCTIONAL TEST and self~test frequencies. . .. The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.3-27b LBIKR 3:8927 Page 20 of 197
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3. 3. 1. 1. 13 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The functional testing of control rods, in LCO 3.1.3, "Control Rod OPERABILITY," and SDV vent and drain valves, in LCO 3.1.8, "Scram Discharge Volume (SDV) Vent and pnsert B SR 3.3.1.1.21-1
- h. .~rain Valves," overlaps this Surveillance to provide
~complete testing of the assumed safety function.
1 The 24 month Frequenoy is based on the need to perform thisgur:ueillanoe under the oonditions that apply during a -~~~~~~~~~~---. plant outage and the potential for an unplanned transient if 1 Insert B SR 3.3.1.1.21-2 ~ the gurueillanoe Here performed Hith the roaster at pouer. Operating mi;:perienoe has shmm that these oomponents usually pass the gur:ueillanoe uhen performed at ,the 24 monthFrequenoy, The Surveillance SR 3.3.1.1.14 Frequency is controlled under the This SR ensures that scrams initiated from the Turbine Stop Valve Closure, Trip Oil Pressure-Low and Turbine Control Surveillance Valve Fast Closure, Trip Oil Pressure-Low Functions will Frequency Control not be inadvertently bypassed when THERMAL POWER is Program. ~ 35.4% RTP. This involves calibration of the bypass channels. Adequate margins for the instrument setpoint methodology are incorporated into the actual setpoint. * '. If any bypass channel setpoint is nonconservative (i.e., the Functions are bypassed at~ 35.4% RTP, then the affected ~ Turbine Stop Valve, Trip Oil Pressure-Low and Turbine Control Valve Fast Closure, Trip Oil Pressure-Low Functions are considered inoperable. Alternatively, the bypass channel can be placed in the conservative condition The Surveillance (nonbypass). If placed in the nonbypass condition, this SR Frequency is is met and the channel is considered OPERABLE. controlled under the Surveillance Tho Froquonoy of 24 months is based on engineering judg:montand reliability of tho oompononts. Frequency Control Program. (continued) GRAND GULF B 3.3-28 LBIKR 14Q27 Page 21 of 197
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.15 (continued) REQUIREMENTS gp£ g:g£pmJaE TIME tests aro oonduotod on an 24 month
gTJ>GGEgED TEaT 13!>£Ia. Noto 2 roquiros aTJ>GGK~ED TEaT. 13J>arn Jlnsert B SR 3.3.1.1.22-1 _ Froquenoy to bo dotorminod based on 4 ohannols por trip system., in lieu of tho g ohannols spooifiod in Tabla J J. 1 1 1 for tho Th4aP 7 Closure Funotion. This Froquonoy is based on tho logia intorrolationships of tho uarious
- ohannols roquirod to produoo an gp£ soram signal.
This Froquonoy is oonsistont uith tho typioal irn;iustry rofuoling oyolo and is based upon plant operating o.H:porionoo, uhioh shous that random. failures of The Surveillance instrumentation oom.ponents oausing serious timo degradation, Frequency is* but not ohannol failure, aro infrequent. controlled under the Surveillance SR 3.3.1.1.16 and SR 3.3.1.1.18 Frequency Control Program. Deleted (continued) GRAND GULF B 3.3-29a LB9CR 14034 Page 22 of 197
RPS Instrumentation B 3.3.1.1 BASES AA 3 3 §J 20 3 3 2] 3 3 22 ?Pd 3 3 23 continue J! SR 3. 3 .1.1. 20 i A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform,the intended function. For the APRM Functions, this test supplements the automatic self-test functions that operate continuously in the APRM/OPRM and voter channels~ The CijANNEL FUNCTIONAL TEST covers the APRM/OPRM channels (including recirculation flow, processing -- applicable to Function 2.b only), the 2-0ut-Of-4 Voter channels, and the interface connections into*the RPS trip systems from the voter channels. Any setpoipt The Surveillance adjustment shall be consistent with the assumptions of the Frequen,cy is current plant-specific setpoint methodology. controlled und~r the Surveillance The 1~4 day F~equonay of SR 3.3.1.1.20 is based on tho reliability analysis of Roforenae 15. (~JOTE: Actual uoting Frequency Control logia of the 2 Out Of 4 Voter Funation>is tested as part of Program. sg 3.3.1.1.21.) Note 1 is provided for APRM Function 2.a that requires this SR to be performed within 12 hours of entering MODE 2 from MODE 1. Testing the MODE 2 APRM Function cannot be performed in MODE 1 without utilizing jumpers or lifted leads This note allows entry into MODE 2 from MODE 1 if the associated Frequency is not met per SR 3.0.2. Note 2 is provided for APRM Functions 2.a, 2.b, and 2.c to clarify the APRM/OPRM channels and 2-0ut-Of-4 Voter channels are includ~d in the CHANNEL FUNCTIONAL TEST Note 3 is provided for APRM Functions 2.d and 2.f to clarify < Move to SR the APRM/OPRM channels and the 2-0ut-Of-4 Voter channels 3.3.1.1.13 (Insert B plus the flow input function, excluding the flow SR 3.3.1.1.21-1) > transmitters, are included in the CHANNEL FUNCTIONAL TEST. sg 3.3.1.1.21 The LOGIC SYSTEM FUNCTIONAL TEST for APRM Function 2.e APRM simulates APRM and OPRM trip conditions at the 2-0ut-Of-4 Voter channel inputs to check all combinations of two tripp~d inputs to the 2-out-of-4 logic in the voter channels
~-related redundant RPS relays. ,The test is only r uired to include the voting logic of the 2-0ut-Of-4 Voter channels and RPS relays not tested as part of the CHANNEL
+
t
.FUNCIONAL TEST.
(continued) GRAND GULF B 3.3-29b LBIKR 10027 Page 23 of 197
RPS Instrumentation B 3.3.1.1 BASES APRM/OPRM instrumentation
£URSJ"EULLANCB SR 3.3.1.1.21 (eontinued)
RBQUIRBMKNT£
< Move to SR 3.3.1.1.13 (Insert B SR 3.3.1.1.21-2) > e per10 1c ca 1 ra ions
~1+-i----.:isew-e~~h~o~u&rCEBs-1-) provide an indirect test of LPRM interfaces including detectors. The design of the equipment allows virtually all testing and routine adjustments to be performed with no changes to the configuration (e.g., no disconnecting wires), so the risk of problems caused by the normal operation of the system is greatly reduced.
£R 3. 3 .1.1. 22
< Move to SR 3.3.1.1.15 (Insert B SR 3.3.1.1.22-1) > RPS RESPONSE TIME for the APRM 2-0ut-Of-4 Voter ction 2.e includes the output relays of the voter and the associated RPS relays and contactors. (The digital portion the APRM and 2-0ut-Of-4 Voter channels are excluded from S RESPONSE TIME testing because self-testing and calibration time base of the digital electronics. Confirmati time bas'e is adequate to assure required response met. Neutron detectors are excluded from RPS RES testing because the principles of detector operat' virtually ensure an instantaneous response time.) APRM and OPRM RB£PON£B Tnrn tests are eondueted on a 2 4 month STAGGBRBD TB£T BASIS. The ~Joto requires the STAGGBRBD
, TB.ST BA.SI£ to be determined based on four ehannels of APRM outputs and four ehannels of OP:H:M outputs, (total "n" 8) being tested on an alternating basis. This allm.rn the STAGGBRBD TBST BASIS Frequene:y for Funetion 2.e to be determined based on B ehannels rather than the four aotual 2 01:1t Of 4 Voter ohannels.
The redundant outputs from the 2 Out Of 4 Voter ohannel (two for APRM trips and two for OPRM trips) are eonsidered part of the same ehanne1,* but the OPRM and APRM outputs are eonsidered to be separate ehannels for applieation of SR 3.3.1.1.22, so "n" 8. The note further requires that testing_OPRM and APRM outputs from a 2 Out Of 4 Voter be alternated. (continued) GRAND GULF B 3.3-29c LBDCR 10Q27 Page 24 of 197
RPS Instrumentation B 3.3.1.1
&R 3.3.1.1.22 (eontinued)
(eontinued) GRAND GULF B 3.3-29d LBDCR 17004 Page 25 of 197
RPS Instrumentation B 3.3.1.1
> ~
BASES~~ REFERENCES 1. UFSAR, Figure 7.2-1.
- 2. UFSAR, Section 5.2.2.
- 3. UFSAR, Section 6.3.3.
- 4. UFSAR, Chapter 15.
- 5. UFSAR, Section 15.4.1.
- 6. NED0-23842, "Continuous Control Rod Withdrawal in the Startup Range," April 18, 1978.
- 7. UFSAR, Section 15.4.9.
( continued) GRAND GULF B 3.3-29e
~ LBDCR 17004 Page 26 of 197
SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.1 and SR 3.3.1.2.3 (continued) REQUIREMENTS gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including tndica~ion and readability. If a channel is The Surveillance
- outside the criteria, it may be an indication that the instrument has drifted outside its limit.
Frequencies are controlled under the Tho Frequency of once every 12 hours for gg 3.3.1.2.1 is Surveillance based on operating oxporionao that demonstrates channel Frequency Control failure is rare. While in D40DEa 3 and 4, roaativity changes are not mcpoctodf therefore, tho 12 hour Frequency is Program. relaxed to 24 hou:ps for gg] 3 1.2,3. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO. SR 3 . 3 . 1. 2 . 2 To provide adequate coverage of potential reactivity changes in the core, one SRM is required to be OPERABLE in the quadrant where CORE ALTERATIONS are being performed, and the other OPERABLE SRM must be in an adjacent quadrant containing fuel. Note 1 states that this SR is required to be met only during CORE ALTERATIONS. It is not required to be met at other times in MODE 5 since core reactivity changes are not occurring. This Surveillance' consists of a review of plant logs to ensure that SRMs required to be OPERABLE for given CORE ALTERATIONS are, in fact, OPERABLE. In the event that only one SRM is required to be OPERABLE, per Table 3.3.1.2-1, footnote (b), only the a. portion of The Surveillance this SR is required. Note 2 clarifies that more than one of Frequency is the thr.ee requirements can be met by the same OPERABLE SRM. controlled under the Tho 12 hour Frequency is based upon operating experience and Surveillance supploFRonts operational aontrols over refueling activities, irhich include stops to ensure that tho ggoos required by tho Frequency Control LCO are in the proper quadrant. Program. (continued) GRAND GULF B 3.3-36 Revision No. 0 Page 27 of 197
$RM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3. 3. 1. 2 . 4 REQUIREMENTS
-t-- ( continued) This Surveillance consists of a verification of the SRM instrument readout to ensure that the SRM reading is greater than a specified minimum-count rate. This ensures that 'the detectors are indicating count rates indicative of neutron flux levels within the core. Verification of the signal to noise ratio also ensures that the detectors are 'inserted to a normal operating level. In a fully withdrawn condition, the detectors are sufficiently removed from the fueled region of the core to essentially eliminate neutrons from reaching the detector. Any count rate obtained while fully withdrawn is assumed to be "noise" only. With few fuel assemblies loaded, the SRMs will not have a high enough count rate to satisfy the SR. rherefore, allowances are made for loading sufficient "source" ~aterial, in the form of irradiated fuel assemblies, to establish the minimum count rate. To accomplish this, the SR is modified by a Note that states that the count rate is 1 not required to be met on an SRM that has less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies are in the associated core quadrant.* With four,or less fuel assemblies loaded around each SRM and no other fuel assemblies in the associated quadrant, even wtth a control rod withdrawn the The Surveillance configuration will not be critical. Frequency is controlled under the Surveillance tha raquirad channals ara fraquantly monitorod Frequency Control raaotivity ohangos are ooourrin'g. Whan no raactivity Program. ohangas ara in prograss, tha Fraquancy is rala1rnd from 12 hours to 24 hours. SR 3 . 3 . 1. 2 . 5 Performance of a CHANNEL FUNCTIONAL TEST demonstrates the The Surveillance associated channel will function properly. Frequency is controlled under the Surveillance Frequency Control Program.' '
, ( continued)
GRAND GULF B 3.3-37 RevisioA No. 1 Page 28 of 197
SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.5 (continued) REQUIREMENTS The Note to the Surveillance allows the,Surveillance to be delayed until entry into the specified condition of the Applicability. The SR must be performed in MODE 2 within 12 hours of entering MODE 2 with IRMs on Range 2 or below. The allowance to enter the Applicability with the 31 day Frequency not met is reasonable, based on the limited time of 12 hours allowed after entering the Applicability and the inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be,expected to maintain steady state operation at this power level. In this event, the 12 hour Frequency is reasonable, based on the SRMs being otherwise verified to be OPERABLE (i.e., satisfactorily performing the CHANNEL CHECK) and the time required to perform the Surveillances. SR 3.3.1.2.6 The Surveillance of a CHANNEL CALIBRATION verifies the Frequency is controlled under the Surveillance Frequency Control Program. be adjusted. The designed to have a relatively constant sensitivity over the range, and with an accuracy specified for a fixed useful life. The Note tb the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the Applicability. The SR must be performed in MODE 2 within 12 hours of entering MODE 2 with IRMs on Range 2 or below. The allowance to enter the Applicability with the 24 monthFrequency not met is reasonable, based on the limited time of 12 hours allowed after entering the Applicability and the inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be expected to maintain steady state operation at this power level. In this event, the 12 hour Frequency'is reasonable, based on the SRMs being (continued) GRAND GULF B 3.3-38 LBQCR 13043 (\ Page 29 of 197
Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE SR 3.3.2.1.1, SR 3.3.2.1.2, SR 3.3.2.1.3, and REQUIREMENTS SR 3.3.2.1.4 (continued) control rod block occurs. Proper operation of the RWL is verified by SR 3.3.2.1.1 which verifies proper operation of the two-notch withdrawal limit and SR 3.3.2.1.2 which verifies proper operation of the four-notch withdrawal limit. Proper operation of the RPC is verified by SR 3.3.2.1.3 and SR 3.3.2.1.4. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. As noted, the SRs are not required to be performed until 1 hour after specified The Surveillance conditions are. met (e.g., after any control rod is withdrawn Frequencies are in MODE 2). This allows entry into the appropriate controlled under the conditions needed to perform the required SRs. ~ Surveillance Frequencies are based on reliability analysis (Ref. 7). Frequency Control Program. SR 3 . 3 . 2 . 1. 5 The LPSP is the point at which the RPCS makes the transition between the function of the RPC and the RWL. This transition point is automatically varied as a function of power. This power level is derived from the power range {_ neutron monitoring system (one channel to each trip system). I' These power setpoints must be verified periodically to be within the Allowable Values. If any LPSP is nonconservative, then the affected Functions are considered inoperable. Since this channel has both upper and lower required limits, it is not allowed to be placed in a condition to enable either the RPC or RWL Function. Because The Surveillance main turbine bypass steam flow can affect the LPSP Frequency is nonconservatively for the RWL, the RWL is considered controlled under the inoperable with any main turbine bypass valves open. ~ Surveillance Frequency of 92 days is based on the sotpoint ~othodology utili~od for these channels. Frequency Control Program. SR 3 . 3 . 2 . 1. 6 This SR ensures the high power function of the RWL is not bypassed when power is above the HPSP. The analytical limit for the HPSP is 70%. The power level is derived from the .J power range neutron monitoring system. Periodic testing of . l' the HPSP channels is required to verify the setpoint to be less than or equal to the limit. Adequate margins in accordance with setpoint methodologies are included. If the HPSP is nonconservative, then the RWL is considered inoperable. Alternatively, the HPSP can be placed in the conservative condition (nonbypass). If placed (continued) GRAND GULF B 3.3-46 UUKR 14Q27 Page 30 of 197
Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE SR 3.3.2.1.6 (continued) REQUIREMENTS in the nonbypassed condition, the SR is met and the RWL would not be considered inoperable. Because main turbine The Surveillance bypass steam flow can affect the HPSP nonconservatively for Frequency is the RWL, the RWL is considered inoperable with any main controlled under the turbine bypass valve open. The Froquenoy of 92 days is Surveillance based on tho sotpoint methodology utilized for those ohannols, Frequency Control Program. SR 3 . 3 . 2 . 1. 7 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology. Any setpoint adjustment shall be consistent The Surveillance with the assumptions of the current plant specific setpoint Frequency is methodology. controlled under the Surveillance Tho Froquonoy is based upon tho assumption of tho magnitude of equipment drift in tho sotpoint analysis. Frequency Control Program. SR 3 . 3 . 2 . 1. 8 The CHANNEL FUNCTIONAL TEST for the Reactor Mode SwitchC Shutdown Position Function is performed by attempting to withdraw any control rod with the reactor mode switch in the shutdown position and verifying a control rod block occurs. As noted in the SR, the Surveillance is not required to be performed until 1 hour after the reactor mode switch is in the shutdown position, since testing of this interlock with the reactor mode switch in any other position cannot be performed without using jumpers, lifted leads, or movable The Surveillance limits. This allows entry into MODES 3 and 4 if the Frequency is 24 month Frequency is not met per SR 3.0.2. controlled under the Surveillance Tho 24 month Froquonoy is 'based on tho need to perform thisauruoillanco under tho conditions that apply during a Frequency Control plant outage and tho potential for an unplanned transient if Program. tho auruoillanoo uoro performed Hith tho roaotor at poHor. (continued) GRAND GULF B 3.3-47 LBDCR 14034 Page 31 of 197
C:on:trol Rod BJt>ck Instrumentation
. . s.'3.3.i.i SVR,VEILLA~C.E SR 3.'.3.2.1.9 REQUIREMENTS
.*. cconti nued) Leo. 3\ L3. and u::o, 3 ~1. 6 ma.y require indi:Vidual control rods to he b}ipas_sed in RAcs to aJ]ow fosertiorf of* *an fooperable control *.rod or :corre.ction *.of a .tontrpl rod pctttern rt'<:>t +n .
, comp}iance wftt1 ~PWS.. Wlth the contrqt ror;is bypa?sed: fn the
~ACS' the RPC wi)J riO:t c:ontrol . ~h~i m.pvement of th~?e bypassed cpnfroT r9ds. Iri~j dual r~.q~,r~4 vi ~ont17gl f(}d? m,ay- c:t]SQ Q_I:!
tcr be hypcis 1¢d ~o allow cont_:; ni;i6~f wiJbclrawal Nr detefrminirJ9; the Jocatidn' of.* l~aking ft1.el 'ass~mblie5, adjiJ.stment . bf cdnfrol *_ rod s:peed'. 'or control rod :scram ti me. testing. *. :To ens.ure the proper bypassing :an<f *movement of . those affected control rods~ as~tond Jicensed operato:t or pther:- quatffieci: m~mher of the t:e,c:nrdcaJ st:aff must verff.y* the qypassi ng c1nd* movem~nt of these corrtroJ ro~s ts'* in a confprm~nc~ \NJth ~ppJkable an.alys_~~**.. As noted,.qnly ,on~ bypa~sed~ontr?lrod restfi ction minJniizes th~ poteqti al
- a
'irya.y*b~ inoved a-i; ~lmei Thts .*.. .
rat.e ;of* c:h~nge a:f
- feactiVity. Cdmplia.nte with thi5 SR allows' the*RPC 'and RWL td be OPERABLE With these control rods bypassed~ . .
- REFERENCE$ L LJfS,AR, ;Se.ction 7.6.i.?.'3.
UFSAR, 'Set{,*Qn *15. 4. 2 ~-
*.NEDE~240ll""'.P_;A; 1
'Genera1*. Electric standard Ap'plfc:ati9n for Reactor Fuel'i (latest appfoVed. revfs16hJ *.
_i'M9d1.f+cadon.s to the Requirements: for Control Rod Drop Acci,dent**Mft:ig~ti*ng Systems~!'- BWR Ovm~rs; Group,, July l~.86._ 5 *. NEDO-q?-31, IIBarjk~d Pqsftiorf Withd(~Vlal Se.quen,ce:/' Jahuary 1977. * * * * * ** NRC SEff, . Acceptance <>f.. gefereodng :,of Lic¢nsing: Topi~al Report NEDE--240ll~P.;.;A, ".Generai Electric. s.:t:andard Application for Reactor Fuel, 8~y.isjcm 8, Am~nclmE!nt: 17/' Dece111qer 27, 1~87~
- 7. NEDC 30891 P A, "Tech~icaJ 5pecific.:~~ierl ~mp_~ey*e~~r=,i AFialysis fer= B'. 1R: $efitrel Re.a ~{l~d(;It1'.ftFtlfflEl"ltatieF1,,J' 1
Ottol3er 1988. * ** * ** * * * * * * * ** * *
- 8. ~J~-9C :3309~0- ~.,. Li CeAS~R§ Tep{cal R@f36F'E (e,r;:;taliJt 11 P'res.st:.1,=e Pow.er Uprate," Rcvisjefl 4, ~1:rly 2003.
BJ. 3-48 Page 32 of 197
PAM I~strumentation B 3.3.3.1 BASES ACTIONS E.l (continued) The allowed Completion Times are reasonable, based on operating experience, to reach the required plant condition from full power conditions in an orderly manner and without challenging plant systems. F.l Since alternate means of monitoring primary containment area radiation have been developed and tested, the Required AGtion is not to shut down the plant but rather to initiate actions to prepare and submit a Special Report.to the NRC. These alternate means may be temporarily installed ifr
- the
*normal PAM channel cannot be restored to OPERABLE status*
within the allotted time. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels. The Special Report shall be submitted in accordance with 10CFR50.4 within 14 days of entering Condition F. SURVEILLANCE The following SRs apply to each PAM instrumentation Function REQUIREMENTS in Table 3.3.3.1-1 except as noted below. SR 3 . 3 . 3 . 1. 1 Performance of the CHANNEL CHECK ~Ii@@ @ 8Jf) ;n el.ayr2 ensures that a gross instrumentation failure has'not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a simil~r parameter on other channels.* It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more seri;us. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. The high radiatio~ instrumentation should be compared to similar plant instruments located throughout the plant. (continued) GRAND GULF B 3.3-59 RevisioA No. 0 Page 33 of 197 ' \
PAM Instrumentation B 3.3.3.1 BASES SURVEILLANCE SR 3.3.3.1.1 (continued) REQUIREMENTS Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including isolation, indication, and readability. If a channel is outside the criteria, it may be an indication The Surveillance that the sensor or the signal processing equipment has Frequency is drifted outside itsilimit. controlled under the Surveillance Frequency Control of Program. a given function in any 31 day intorual is rare. CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of those displays associated with the required channels of this LCO. ([]1----- SR 3.3.3.1.~Deleted SR 3 . 3 . 3 . 1. 3 For all Functions a CM.l\~JwgL CALigR.ATIO~J is performed every 2 4 Ffl.ontho, or apprmdFHatoly at every refueling. CHANNEL CALIBRATION is'a complete check of the instrument loop The Surveillance including the sensor. The test verifies that the channel Frequency is responds to the measured parameter with the necessary range controlled under the and accuracy. Tho Frequency is based on operating Surveillance experience and consistency uith the typical industry refueling-cycles Frequency Control Program. For Functions 12 and 13 the CHANNEL CALIBRATION consists of an electronic calibration of th~ channel, not including the detector, for range decades above lOR/hr and a one point calibration check of the detector below lOR/hr with an installed or portable gamma source. The neutron detectors are excluded from the CHANNEL CALIBRATION because ,they cannot readily be adjusted. The detectors are ___fission (continued) GRAND GULF B 3.3-60 1.JrncR 1.:eg4 :e Page 34 of 197
Remote Shutdown System B 3.3.3.2 BASES ACTIONS A.1 (continued) The Required Action is to restore the Function (both divisions, if applicable) to OPERABLE status within 30 days. The Completion Time is based on operating experience and the low probability of an event that would require evacuation of the control room. B.1 If the Required Action and associated Completion Time of Condition A are not met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours. The allowed Completion Time is reasonable, based on operating experience, to reach the required MODE from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.3.3.2.1 REQUIREMENTS Performance of the CHANNEL CHECK c re@@ @r3 ©1 ~eJ~ ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same paramet~r should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. As specified in the Surveillance, a CH~NNEL CHECK is only required for those. channels that are normally energized. (continued) GRAND GULF B 3.3.-65 R@Yi :!5ii 81'1 ~Je. 8 Page 35 of 197
Remote Shutdown System B 3.3.3.2 BASES SURVEILLANCE SR 3.3.3.2.1 (continued) REQUIREMENTS The Frequency is based upon plant operating experience that demonstrates channel failure is rare. The Surveillance Frequency is controlled under the Surveillance Frequency SR 3.3.3.2.2 Control Program. SR 3.3.3.2.2 v~rifies each required Remote Shutdown System transfer switch and control circuit performs the intended function. This verification is performed from the remote shutdown panel and locally, as appropriate. Operation of the equipment from the remote shu~down panel is not necessary. The Surveillance can be satisfied by performance of a continuity check. This will ensure that if the control room becomes inaccessible, the plant can be placed and The Surveillance, maintained in MODE 3 from the remote shutdown panel and the Frequency is local control stations. However, this Surveillance is not controlled under the performed only during a plant ~utage. Surveillance Hhen Frequency Control Program. SR 3.3.3.2.3 The Surveillance CHANNEL CALIBRATION is a compleLe check of the instrument Frequency is loop and the sensor. The test verifies the channel responds to measured parameter values with the necessary range and controlled under the Surveill_ance Frequency Control Program. REFERENCES 1. 10 CFR 50, Appendix A, GDC 19. GRAND GULF B 3.3-66 LBDER 13043 Page 36 of 197
EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3 . 3 . 4 . 1. 1 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel' will perform the intended function. Any setpoint adjustment shall be The Surveillance consistent with the assumptions of the current plant Frequency is specific setpoint methodology. controlled under the Surveillance The Frequenay of 92 days is based on reliability analysis (gof 5) Frequency Control Program. SR 3
- 3
- 4
- 1. 2 The calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the setting is discovered to be less conservative than the Allowable Value specified in SR 3.3.4.1.3. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be The Surveillance equal to or more conservative than accounted for in the Frequency is appropriate setpoint methodology.
controlled under the Surveillance Frequency Control Program. SR 3 . 3 . 4 . 1. 3 CHANNEL CALIBRATION is a tomplete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequency is methodology. controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF. B 3.3-74 Revision No. G Page 37 of 197
EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3.3.4.1.4 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific* channel. The system functional test of the pump breakers is The Surveillance included as a part of this test, overlapping the LOGIC SYSTEM FUNCTIONAL T_EST, to provide complete .testing of the Frequency is associated safety function. Therefore, if a breaker is controlled under the incapable of operating, the associated instrument channel Surveillance would also be* inoperable. Frequency Control The 2 4 'month Frequency iB baBed on the need to perform thi B Program. gypreillanoe under the oonditions that apply dYring a plant oytage and the potential for an Ynplanned transient if the gypreillanoe uere performed uith the reaotor at poHer Operating 011.perienoe has Bhmm these components UBYally pass the gurs:reillanoe test uhen performed at the 2 4 month Freqyeno:y, SR 3.3.4.1.5 This SR ensures that an EOC-RPT initiated from the TSV Closure,.Trip Oil Pressure-Low and TCV Fast Closure, Trip Oil Pressure O Low Functions will not be inadvertently bypassed when THERMAL POWER is~ 35.4% RTP. This involves' calibration of the bypass channels. Adequate mar gins for 1 the instrument setpoint methodologies are incorporated into the actual setpoint. Because main turbine bypass flow can affect this setpoint nonconservatively (THERMAL POWER is derived from the power range Neutron Monitoring System, the ~ main turbine bypass valves must remain closed at THERMAL POWER~ 35.4% RTP to ensure that the calibration remains valid. If any bypass channel's setpoint is nonconservative (i~e., the Functions are bypassed at~ 35.4% RTP either due to open main turbine bypass _valves or other reasons), the affected TSV Closure, Trip Oil Pressure C Low and TCV Fast Closure, Trip Oil Pressure-Low Functions are considered inoperable. Alternatively, the bypass channel can be placed The Surveillance in the conservative condition (nonbypass). If placed in the nonbypass condition, this SR is met and the channel
- Frequency is considered OPERABLE.
controlled under the Surveillance The Freqyene 1~ of 2 4 months has shmm that channel bypass Frequency Control failYres betHeen syccessi:ue tests are rare. Program. (continued) GRAND GULF B 3.3-75 LBDER 16224 Page 38 of 197
EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3 . 3 . 4 . 1. 6 REQUIREMENTS (continued) This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. The EOC-RPT SYSTEM RESPONSE TIME acceptance criteria are included in the applicable plant procedures. A Note to the Surv~illance states that breaker interruption time may be assumed from the most recent performance of SR 3.3.4.1.7. This is allowed since fhe time to open the contacts after energization of the trip coil and the arc suppression time are short and do not appreciably change, due to the design of the brea~er opening device and the fact that the breaker is not routinely cycled. goc gpT aYaTgM*ggaPOwag TIMg tests are aonduatod on an 2 4 month aTAccgggp nrnT :gn a Ia. gaah test inoludos tHo turbine oontrol value channels from one trip system and trm The Surveillance turbine stop value_ ohannols from tho other trip system. Frequency is Response times cannot be determined at power because controlled under the operation of final actuated devices is required. Therefore, I I o I I I Surveillance refueling ayalo and is based_ upon plant operating Frequency Control oxporionao, uhiah shous that random failures of Program. instrumentation components that aauso serious response time degradation, but not channel failure, are infrequent oaaurronaos SR 3 . 3 . 4 . 1. 7 This SR ensures that the RPT breaker interruption time is provided to the EOC-RPT SYSTEM RESPONSE TIME test. Breaker Interruption time is defined as Breaker Response time plus Arc Suppressiori time. Breaker Response is the time from application of voltage to the trip coil until the main contacts separate. Arc Suppression is the time from main contact separation until the complete suppression of the electrical arc across the open contacts. Breaker Response shall be verified by testing and added to the manufacturer's design Arc Suppression time of 12 ms to determine Breaker Interruption time. The breaker arc suppression time shall be validated by the performance of periodic contact gap (continued) GRAND GULF B 3.3-76 LBIKR 13043 Page 39 of 197
EOC~RPt tnstrume.ntati,on. B 3 .3.4 .1
*BASES SURVEILLANCE SR . 3.3.4.1.7. (continued)'
REQUiREMENT.S mec1surements and. high potential tes"ts *on. the bhfaker v~cuum
*; nterrupt.ers in accordance with plant proced.ures. *+ht! .
69 meF1th FreE1lieAey. ef the testing. is. ea sea .eA. tt:ie* cliff, etil ty ef fJerfarmi Ag tile t.est aflEI the reli aei lity ef the eir.e_li ft
- 13.reakers.
REFERENCES UFSAR, *section 7 .6.i.'8. The Surveillance UFSAR, *Section 5.2.2. Frequency 1s controlled under the Surveillance
- 3. UFSAR, Sections 15.l.2 and l5.L3.
Frequency Control :4. UFSJ\R, Sect.ions* is.2./2, 15.2.3 and 15.:t.s.
- 5. GtNE~i70~06~1, . :Bases for changes To Surveillance Test Intervals And Allowed Out-Of~Serv*ice limes Far* * .*
- SelecteQ Instrumentation T~C'~~ical *specificitlons;"
February l99L *
- GRAND GULF Page 40 of 197
ATWS-RPT Instrumentation B 3.3.4.2 BASES ACTIONS D.l and D.2 (continued) recirculation pump may be removed from service since this performs the intended Function of the instrumentation (Required Action D.1). The allowed Completion Time of 6 hours is reasonable, based on operating experience, both to reach MODE 2 from full power conditions and to remove a recirculation pump from service in an orderly manner and without challen~ing plant systems. SURVEILLANCE The Surveillances are modified by a Note to indicate that REQUIREMENTS when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 2) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the recirculation pumps will trip when necessary. SR 3.3.4.2.1 Performance of the CHANNEL CHECK ~R~8 8 @FJ 1~ hq~rs ensures that gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is (continued) GRAND GULF B 3.3-84 Revision No. 0
)
Page 41 of 197
ATWS-RPT Instrumentation B 3.3.4.2 BASES SURVEILLANCE SR 3.3.4.2.1* (continued) REQUIREMENTS outside the criteria, it may be an indication that the The Surveillance instrument has drifted outside its limit. Frequency is controlled under the Surveillance supplements less formal, but more frequent, checks of Frequency Control channels during normal operational use of the displays Program. associated with the required channels of this LCO. SR 3.3.4.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the The Surveillance assumptions of the current plant specific setpoint Frequency is
- methodology.
controlled under the Surveillance Frequency Control Program. SR 3.3.4.2.3 Calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in SR 3.3.4.2.4. If the trip setting is discovered to be less conservative than the setting accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than The Surveillance accounted for in the appropriate setpoint methodology. Frequency is controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.3-85 , RevisioA No. 0 Page 42 of 197
ATWS-RPT Instrumentation B 3.3A.2 BASES SURVEILLANCE SR 3.3.4.2.4 REQUIREMENTS
* ( continued) A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequency is methodology.
controlled under the Surveillance Frequency Control Program. I SR 3.3.4.2.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific cqannel. The system functional test of the pump breakers, included as part of this Surveillance, overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the assumed safety function. Therefore, if a breaker is The Surveillance incapable of operating, the associated instrument channel(s) Frequency is would be inoperable. controlled under the Surveillance Frequency Control tho Program.
, REFERENCES 1. UFSAR, Section 5.4.1.7.10.
- 2. NEDE-770-06-1, "Bases For Changes To Surv.eillance Test Intervals and Allowed Out-of-Service Times For Selected Instrumentation Technical Specifications,"
February 1991. GRAND GULF B 3.3-86 LBDCR 14Q~4 Page 43 of 197
ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3 . 3 . 5 . 1. 1 REQUIREMENTS (continued) Performance of the CHANNEL CHECK onoo euery 12 h01,1n; ensures that a gross 1 failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrum~nt channels monitoring the same parameter should read approximately the same value. Significant deviations 1 between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is The Surveillance outside the criteria, it may be an indication that the Frequency is instrument has drifted outside its limit. controlled under the Surveillance doffionstrates rare. Frequency Control supplements less formal, but more frequent, checks of Program. channels during normal operational use of the displays associated with the channels required by the LCO. SR 3 . 3 . 5 . 1. 2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the i intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. The required setpoint adjustments include a The Surveillance calibration of the HPCS Reactor Vessel Water Level - Low Frequency is Low, Level 2 Function confirmation delay permissive.
- controlled under the Tho Froquonoy of 92 days is based on tho reliability Surveillance analyses of ggferenoe 4.
Frequency Control Program. (continued) GRAND GULF B 3.3-121 RevisioR No. 2 Page 44 of 197
ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3 . 3 . 5 . 1. 3 REQUIREMENTS (continued) The calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be not within its required Allowable Value specified in Table 3.3.5.1-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channe1 performance is still wi~hin the requirements of the plant safety analyses. Under these conditions, the setpoint must be readjusted'to be The Surveillance equal to or more conservative than the setting accounted for Frequency is in the appropriate setpoint methodology. controlled under the Surveillance Tho Frequency of 92 days is based on-tho reliability analysis of ~oforonco 4 Frequency Control Program. .SR 3.3.5.1.3 for Function 3.d, Condensate Storage Tank Level
-Low, is modified by two Notes as identified in Table 3.3.5.1-1. The first Note requires evaluation of channel performance for the condition where the as-found setting for the channel setpoint is outside its as-found tolerance but conservative with respect to the Allowable Value. Evaluation of channel performance will verify that the channel will continue to behave in accordance with safety analysis assumptions and the channel performance assumptions in the setpoint methodology. The purpose of the assessment is to ensure confidence in the channel performance prior to returning the channel to service. For channels determined to be OPERABLE but deg"i-aded, after returning the channel to service the performance of these channels will be evaluated under the plant Corrective Action Program. Entry into the Corrective Action Program will ensure required review and documentation of the condition.
The second Note applied to SR 3.3.5.1.3 for Function 3.d, Condensate Storage Tank Level -Low, requires that the as-left setting for the channel be within the as-left tolerance of the Nominal Trip Setpoint (NTSP). Where a setpoint more conservative than the NTSP is used in the plant surveillance procedures, the as-left and as-found tolerances, as applicable, will be applied to the surveillance procedure setpoint. This will ensure that sufficient margin to the Safety Limit and/or Analytical Limit is maintained. If the as-left channel setting cannot be returned to a setting within the as-left tolerance of the (continued) GRAND GULF B 3.3-122 LBDCR 11047 Page 45 of 197
ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3.3.5.1.3 (continued) REQUIREMENTS NTSP, then the channel shall be declared inoperable. The second Note also requires that NTSP and the methodologies for calculating the as-left and the as-found tolerances be in the TRM. SR 3.3.5.1.4 and SR 3.3.5.1.5 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequencies are methodology. controlled under the Surveillance Frequency Control Program., SR 3.3.5.1.5 for Function-3.d, Condensate Storage Tank Level-Low, is modified by two Notes as identified in Table 3.3.5.1-1. The first Note requires evaluation of channel performance for the condition where the as-found setting for the channel setpoint is outside its as-found tolerance but conservative with respect to the Allowable Value. Evaluation of channel performance will verify that the channel will continue to behave in accordance with safety analysis assumptions and the channel performance assumptions in the setpoint methodology. The purpose of the assessment is to ensure confidence in the channel performance prior to returning the channel to service. For channels determined to be OPERABLE but degraded, after returning the channel to service the performance of these channels will be evaluated under the plant Corrective Action Program.- Entry,into the Corrective Action Program will ensure required review and documentation of the condition. The second Note applied to SR 3.3.5.1.5 for Function 3.d, Condensate Storage Tank Level -Low, requires that the as-left setting for the channel be within the as-left tolerance of the NTSP. Where a setpoint more conservative than the NTSP is used in the plant surveillance procedures, the as-left and as-found tolerances, as applicable, will be applied to the surveillance procedure setpoint. This will ensure that sufficient margin to the Safety Limit and/or Analytical
/ ( continued)
GRAND GULF B 3.3-122a LBDCR 11Q47 Page 46 of 197
ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3 . 3 . 5 . 1. 6 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.1, LCO 3.5.2, LCO 3.8.1, and LCO 3.8.2 overlaps this The Surveillance Surveillance to provide complete testing of the assumed Frequency is safety function. controlled under the Surveillance Frequency Control outage ( mrnopt for Division III' uhich can be any Program. pporational condition) and tho potential for unplanned transients if tho ~urvoillanco Hero porforH-1od Hith tho reactor at pouor. Operating m£perience has shmm those coFRpononts usually pass tho ~uruoillanco Hhen performed at tho 24 H-lonth Frequency, REFERENCES 1. UFSAR, Section 5.2.
- 2. UFSAR, Section 6.3.
- 3. UFSAR, Chapter 15.
- 4. NEDC-30936-P-A, "BWR Owners' Group Technical Specification Improvement Analyses for ECCS Actuation Instrumentation, Part 2," December 1988.
- 5. Regulatory Guide 1.105, "Setpoints for Safety-Related Instrumentation," Revision 3.
GRAND GULF B 3.3-123 LBDCR BQ4~ Page 47 of 197
RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE Conditions and Required Actions may be delayed as follows: REQUIREMENTS (a) for up to 6 hours for Functions 2 and 5; and (b) for up (continued) td 6 hours for Functions 1, 3, and 4 provided the associated Function maintains tr.ip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the
'channel must be returned to OPERABLE status or the applicable Conditionrentered and Required Actions taken.
This Note is based on the reliability analysis (Ref. 1) assumption of the average time required to perform channel 0 Surveillance. That analysis demonstrated that_the 6 hour testing allowance does not significantly reduce the probability that the RCIC will initiate when necessary. SR 3.3.5.2.1 Performance of the CHANNEL CHECK onoe every 12 ho1:1rs ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the ~ame value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues\ to operate properly between each CHANNEL CALIBRATION. Agreement criteria are deter~ined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability.' If a channel is The Surveillance outside the criteria, it may be an indication that the Frequency is instrument has drifted outside its limit. controlled under the Surveillance demonstrates ohannel fail1:1re is rare Frequency Control supplements less formal, but more frequent, checks of Program. channel status during normal operational use of the displays, associated with the channels required by the LCO. (continued) GRAND GULF B 3.3-133 RevisioR No. 1 Page 48 of 197
RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE SR 3.3.5.2.2 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be The Surveillance consistent with the assumptions of the current plant Frequency is specific setpoint methodology. controlled under the Surveillange Frequency Control Program. SR 3.3.5.2.3 The calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.5.2-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be The Surveillan,ce re-adjusted to be equal to or more conservative than Frequency is accounted for in the appropriate setpoint methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.5.2.4 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter with the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequency is methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.5.2.4 for Function 3, Condensate Storage Tank Level-Low, is modified by two Notes as identified in Table 3.3.5.2-1. The first Note require evaluation of channel performance for the condition where the as-found setting for (continued) GRAND GULF B 3.3-134 LBDCR 11047 Page 49 of 197
RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE SR 3.3.5.2.5 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in The Surveillance LCO 3.5.3 overlaps this Surveillance to provide complete Frequency is testing of the safety function. controlled under the The 2 4 :month Freql:10noy is based on tho need to !)Orfor:m this Surveillance gur:ueillanoe under the oonditions that a!)!)ly during a !)lant Frequency Control outage and tho !)Otential for an un!)lanned transient if the ~rogram. gupreillanoe Here !)Orfor:m.ed Hith the reaotor at !)OHer. O!)erating m,s:!)erienoe has shmm that these oo:m.ponents usually
!)ass the gur:ueillanoe uhon !)erfor:m.ed at tho 24 :month Frequenoy.
REFERENCES 1. NEDE-770-06-2, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.
- 2. Regulatory Guide 1.105, "Setpoints for Safety-Related Instrumentation," Revision 3.
GRAND GULF B 3.3-135 LBDCR 13043 Page 50 of 197
Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE trip capability. Upon completion of the Surveillance, or REQUIREMENTS expiration of the 6 hour allowance, the channel must be (continued) returned to OPERABLE status or the applicable Condition enterid and Required Actions taken. This Note is based on the reliability analysis (Refs. 5 and 6) assumption of the average time required to- perform channel Surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the PCIVs or drywell isolation valves will isolate the penetration flow path(s) when necessary. SR 3.3.6.1.1 Performance of the CHANNEL CHECK onee euery 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is The Surveillance outside the criteria, it may be an indication that the Frequency is instrument has drifted outside its limit. controlled under the Surveillance Frequency Control Program. The CHANNEL CHECK supplements less formal, but more
, frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO.
r (continued) GRAND GULF B 3.3-168 RevisioR No. 0 Page 51 of 197
Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.2 REQUIREMENTS i (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the The Surveillance assumptions of the current plant specific setpoint Frequency is methodology. controlled under the The Frequency is based on reliability analysis desoribed in Surveillance Referenoes 5 and a. Frequency Control Program. SR 3.3.6.1.3 The calibration of trip units consists of a test to provide a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be
/ less conservative than the Allowable Value specified in Table 3.3.6.1-1. For Function l.c, Main Stearn Line Flow High, there is a plant specific program which *verifies that the instrument channel functions as required by verifying the as-left and as-found settings are consistent,with those established by the setpoint methodology. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be The Surveillance equal to or more conservative than accounted for in the Frequency is appropriate'setpoint methodology.
controlled under the Surveillance Tho Frequonoy of 92 days is based on tho reliability analysis of ~eferences 5 and a. Frequency Control Program. SR 3.3.6.1.4, SR 3.3.6.1.5, and SR 3.3.6.1.7 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaV-es the"channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequencies are methodology. controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.3-169 LBDCR 13043 Page 52 of 197
Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3. 3. 6 .1. 6 and SR 3. 3. 6 .'l. 8 REQUIREMENTS ( continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a1specific channel. The system functional testing performed on The Surveillance isolation valves in LCO 3.6.1.3 and LCO 3.6.5.3 overlaps Frequencies are this Surveillance to provide complete testing of the assumed controlled under the safety function. Tho 2 4 HioHth Froqt10Hoy for aJ;1 3. 3 i 1 @ is based @H tho Hood to*porforHi this at1ruoillaHoo t1Hdor tho Surveillance ooHditioHs that apply duriHg a plaHt outage aHd tho Frequency Control potoHtial for aH uHplaHHod traHsioHt if tho aurvoillaHoo Prog~am. Hero porfonrmd Hith tho roaotor at por.;ror. Tho l@ FElOHth FroquoHoy f*or aJ;1 3. 3. i .1. i is based OH tho ourroHt froquoHoy for porforFEliHg th.is at1ruoillaHoo. OporatiHg oxporioHoo has shmm those ooFapoHoHts usually pass tho auruoillaHoo r1hoH porforHiod at tho listed HlOHth '{ FroquoHoy SR 3.3.6.1.9 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. Testing is performed only on channels where the assumed response time does not correspond to the diesel generator (DG) start time. For channels assumed to respond within the DG start time, sufficient margin exists in the 10 second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response without a specific measurement test. Testing of the closure times of the MSIVs is not included in this Surveillance since the closure time of the MSIVs is tested by SR 3.6.1.3.6. ISOLATION SYSTEM RESPONSE TIME acceptance criteria for this instrumentation is included in the applicable plant procedures. As Noted, the channel sensor may be excluded from response time testing. This allowance to not perform specific response time testing of the sensors is applicable when the alternate testing requirements and restricti6ns of Reference 7 are performed. As stated in Reference 7, analysis has demonstrated that other Technical Specification testing requirements (CHANNEL CALIBRATIONS, CHANNEL CHECKS, CHANNEL FUNCTIONAL TESTS, and LOGIC 'SYSTEM FUNCTIONAL TESTS) and. actions taken in response to NRC Bulletin 90-01 Supplement 1 are sufficient to identify failure modes or degradation in (continued) GRAND GULF B 3. 3-.170 LBDCR 13043 Page 53 of 197
Primary Containment and Drywell Isolation.Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.9 (continued) REQUIREMENTS instrument response times and assure operation of the analyzed instrument loops within acceptable limits. Reference 7 also identifies that there are no known channel sensor failure modes identified that can be detected by response time testing that cannot also be detected by other Technical Specification required surveillances. Therefore, when the requirements, including sensqr types, of Reference 7 are complied with, adequate assurance of the response time of the sensors is provided. This assurance of the response time of the sensors when combined with the response time testing of the remainder of the channel ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. The calibration shall be performed such that fast ramp or step change to system components during calibrations is performed to verify that the response of the transmitter to the input change is prompt. Technicians shall monitor for response time degradation during the performance of calibrations. The Surveillance Technicians shall be appropriately trained to ensure they are aware of the consequences of instrument response time Frequency is degradation. These items are commitments made per Reference controlled under the 8. If the alternate testing requirements of Reference 7 are Surveillance not complied with then the entire channel will be response Frequency Control time tested including the sensors. Program. instrumentation are GonduGtod on an 24 month aTACCE~ED TEaT
~Aaia This test FrsquonGy is Gon.sistont uith*tho typ'iGal industry rofusling Gyals and is bassd upon plant operating SR 3.3.6.1.10 oxporionGo that shmrn that random failures of instrllfflontation Gompononts Gausing serious response time degradation, but not Ghannol failure, are infrequent.
Analysis has shown that with the upper containment pool cavity flooded and the gates removed, adequate time exists to allow operator action necessary to terminate the inventory loss prior to reaching reactor level 3. This The Surveillance analysis takes credit for the pbol level being greater than Frequency is or equal to 22 feet 8 inches above the reactor vessel controlled under the flange. Verifying tho upper Gontainmont pool louol is Surveillance greater than or equal to 22 foot g inGhos on a four hour froquonGy prouidos assurance that tho operators hauo enough Frequency Control time to dstoGt and torm.inato a drain doTm ouont Program. (continued) l GRAND GULF B 3.3-l?Oa Lgl;>CR BQO Page 54 of 197
Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE SR 3.3.6.2.1 REQUIREMENTS (continued) Performance of the CHANNEL CHECK onoo ovary 12 h01,1rs ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the indicated parameter for one instrument channel. to a similar parameter on other channels. It is based on the kssumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is The Surveillance outside the criteria, it may be an indication that the Frequency is instrument has drifted outside its limit. controlled under the Surveillance Frequency ,Control supplements less formal, but more frequent, checks of Program. channels during normal operational use of the displays associated with the channels required by the LCO. SR 3.3.6.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function,. Any setpoint adjustment shall be consistent with the The Surveillance assumptions of the current plant specific setpoint Frequency is methodology. controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.3-181 RevisioA No. 0 Page 55 of 197
Secondary Containme~t Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE SR 3.3.6.2.3 REQUIREMENTS (continued) Calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.6.2-1. If the trip setting is discovered to be less conservative than accou~ted fdr in the appropriate setpoint methodology, but is not beyond the Allowable Value, performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be The Surveillance equal to or more conservative than accounted for in the Frequency is appropriate setpoint methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.6.2.4 and SR 3.3.6.2.5 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequencies are methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.6.2.6 The LOGI.C SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing, performed on SCIVs and the SGT System in LCO 3.6.4.2 and LCO 3.6.4.3, The Surveillance respectively, overlaps this Surveillance to provide complete Frequency is testing of the assumed safety function. controlled under the Surveillance The 24 month Frequenay is based on the need to perform this
~urveillanae under the aonditions that apply during a plant
-t Frequency Control outage and the potential for an unplanned transient if tho Program.
(continued) GRAND GULF B 3.3-182 LBDCR BOB Page 56 of 197
Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE SR 3.3.6.2.6 (continued) REQUIREMENTS Suruoillanoo uoro porformod uith tho roaotor at pouor. Oporating mcporionoo has shoun thoso oompononts usually pass tho &;uruoillanoo Hhon porformod at tho 2 4 month Froquonoy 'h.. SR 3.3.6.2.7 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. Testing is performed only on channels where the assumed response time does not correspond to the diesel generator (DG) start time. For channels assumed to respond within the DG start time, sufficient margin exists in the 10 second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response without a specific measurement test. Testing of the closure times of the isolation dampers is not included in this Surveillance since the closure time of the isolation dampers is tested by SR 3.6.4.2.2. ISOLATION SYSTEM RESPONSE TIME acceptance criteria for this instrumentation is included in the applicable plant procedures. A Note to the Surveillance states that the radiation detectors may be excluded from ISOLATION SYSTEM RESPONSE TIME testing. This Note is necessary because of the difficulty of generating an appropriate detector input signal and because the principles of detector operation virtually ensure an instantaneous response time. Response time for radiation detector channels shall be measured from The Surveillance detector output or the input of the first electronic Frequency is component in the channel. controlled under the Surveillance 24 month STACCE~EQ TEST QASIS. This Froquonoy is oonsistont Frequency Control uith tho typioal industry rofuoling oyolo and is basod upon Program. plant operating mcporionoo, Hhioh shoHs that random failuros of instrurnontation oompononts oausing sorious rosponso timo dogradation, but not ohannol failuro, aro infroquont ooourronoos. (continued) GRAND GULF B 3.3-183 LBDCR BQq, Page 57 of 197
RHR Containment Spray System Instrumentation B 3.3.6.3 BASES ACTIONS C.l and C.2 (continu~d) status within the allowabl~ out of service time, Condition D must be entered and its Required Action taken. The Required Actions do not allow placing the channel in trip since this action' could either cause the initiation or it would not necessarily result in a safe state for the channel in all events. D.1 With any Required Action and associated Completion Time not met, the as;;ociated RHR containment spray subsy~tem may be incapable of performing the intended function and the RHR containment spray subsystem associated with inoperable untripped channels must be declared inoperable immediately. SURVEILLANCE , As, noted at the beginning of the SRs, the SRs for each RHR REQUIREMENTS Containment Spray System Function are located in the SRs column of Table 3.3.6.3-1. The Surveillances are also modified by a Note to indicate that when a channel is played in an inoperable status solely for performance of *required Surveillances, entry into_ associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains RHR containment spray initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered' and Required Actions taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform channel surveillance. That ~nalysis _demonstrated that the 6 hour testing allowance does not signifiQantly reduce the probability that the RHR containment spray will initiate when necessary. SR" 3. 3. 6. 3 .1 Performance of the CHANNEL CHECK e1130 @a@il!') lA R'iiJJr2 ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter (continued) GRAND GULF B 3.3-192 RevisioA No. 0 Page 58 of 197
RHR Containment Spray System Instrumentation B 3.3.6.3 BASES SURVEILLANCE SR 3.3.6.3.1 (continued) REQUIREMENTS indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument,drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is The Surveillance outside the criteria, it may be an indication that the Frequency is instrument has drifted outside its limit. controlled under the Surve.illance Frequency Control supplements less formal, but more frequent, checks of Program. channels during normal operational use of the displays associated with the channels required by the LCO. SR 3.3.6.3.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure the entire channel will perform the intended function. 0 Any setpoint adjustment shall be consistent with the The Surveillance assumptions of the current plant specific setpoint Frequency is methodology. controlled under the Tho Froquonoy of 92 days is based upon tho reliability Surveillance analysis of ~oforonoo] Frequency Control Program. SR ,3
- 3. 6. 3 . 3 The calibration of trip units provides a check of the actual trip setpoints.* The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.6.3-1. If the (continued)
GRAND GULF B 3.3-193 Revision No. 0 Page 59 of 197
,RHR Containment Spray System Instrumentation B 3.3.6.3 BASES SURVEILLANCE SR 3.3.6.3.3 (continued)
REQUIREMENTS trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be The Surveillance readjusted to be equal to or more conservative than Frequency is accounted for in the appropriate setpoint methodology. controlled under the The Frequenoy of 92 days is based upon the reliability Surveillance analysis of geferenoe 3. Frequency Control Program. SR 3.3.6.3.4 and SR 3.3.6.3.5 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequencies are methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.6.3.6 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.6.1.7, "Residual Heat Removal (RHR) Containment The Surveillance Spray," overlaps this Surveillance to provide complete Frequency is testing of the assumed safety function. controlled under the Surveillance gurrreillanoe under the oonditions that apply during a plant Frequency Control outage and the potential for an unplanned transient if tho Program. Surveillanoe Here performed uith the reaotor at power. Operating experienoe has shmm these oomponents usually pass the gurveillanoe uhen performed at the 24 month Frequenoy. (continued) GRAND GULF B 3.3-194 LBDCR 13043 Page 60 of 197
SPMU System Instrumentation B 3.3.6.4 BASES ACTIONS D.l (continued) With any Required Action and associated Completion Time not met, the associated SPMU subsystem may be incapable of performing the intended function and the SPMU subsystem associ~ted with inoperable, untripped channels must be declared inoperable immediately. SURVEILLANCE-- As noted at the beginning of the SRs, the SRs for each SPMU REQUIREMENTS System Function are located in the SRs column of Table 3.3.6.4-1. The 1 Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains suppression pool makeup initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform channef surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the SPMU will initiate when necessary. SR 3.3.6.4.1 Performance of the CHANNEL CHECK once coc+/-J 12 hBetJ?8 ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. (continued) 'GRAND GULF B 3.3-205 RevisioR No. 0 Page 61 of 197
SPMU System Instrumentation B 3.3.6.4 BASES SURVEILLANCE SR 3.3.6.4.1 (continued) REQUIREMENTS Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is The Surveillance outside the criteria, it may be an indication that the Frequency is instrument has drifted outside its limit. controlled under the Surveillance Frequency Control supplements less formal, but more frequent, checks of Program. channels during normal operational use of the displays associated with the required channels of the LCO. SR 3.3.6.4.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the The Surveillance assumptions of the current plant specific setpoint Frequency is methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.6.4.3 The calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.6.4-1 . . If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to. The Surveillance be equal to or more conservative than accounted for in the Frequency is appropriate setpoint methodology. controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.3-206 RevisioA No. 0 Page 62 of 197
SPMU System Instrumentation B 3'.3.6.4 BASES SURVEILLANCE SR 3.3.6.4.4 and SR 3.3.6.4.5 REQUIREMENTS (continued) A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy*. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequencies are methodology. controlled under the Surveillance Frequency Control Program. SR 1 3 . 3 . 6. 4 . 6 The LOGIC SYSTEM FUNCTION~L TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.6.2.4, "Suppression Pool Makeup (SPMU) System," The Surveillance overlaps this Surveillance to provide complete testing of Frequency is the assumed safety function. controlled under the Surveillance Frequency Control Program. pm10r. usually pass Froquonoy. REFERENCES 1. UFSAR, Section 7.3.1.1.9.
- 2. UFSAR, Section 6.2.7.3.
- 3. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," _
February 1991. GRAND GULF B 3.3-207 umrn. B94s Page 63 of 197
Editorial change: delete Relief and LLS Instrumentation
...------extra underline to return B 3.3.6.5 spacing to the correct (continued)
ACTIONS B.l and B.2 (continued) from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE The Surveillances are modified by a Note to indicate that REQUIREMENTS when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains relief or LLS initiation capability, as applicable. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 2) assumption of the average time required to perform channel surveillance. That analysis demonstrated the 6 hour testing allowance does not significantly reduce the probability that the relief and LLS valves will initiate when necessary. SR 3.3.6.5.1 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire *channel will perform the intended function. Any setpoint adjustment shall be The Surveillance consistent with the assumptions of the current plant Frequency is specific setpoint methodology. controlled under the Su.rveillance Tho Froquonay of 92 days is based on tho reliability analysis of goforonao 2. Frequency Control Program. SR 3.3.6.5.2 The calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in SR 3.3.6.5.3. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be (continued) GRAND.GULF B 3.3-212* Revision No. 0 Page 64 of 197
Relief and LLS Instrumentation B 3.3.6.5 BASES SURVEILLANCE SR 3.3.6.5.2 (continued) REQUIREMENTS equal to or more conservative than accounted for in the The Surveillance , appropriate setpoint methodology. Frequency is controlled under the Surveillance Frequency Control Program. SR 3.3.6.5.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant spec~fic setpoint Frequency is methodology. controlled under the Surveillance Frequency Control Program. SR 3.3.6.5.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed for S/RVs The Surveillance in LCO 3.4.4 and LCO 3.6.1.6 overlaps this Surveillance to Frequency is provide complete testing of the assumed safety function. controlled under the Surveillance Frequency Control Program. usually pass FreE3"1:1enoy ~ REFERENCES 1. UFSAR, Section 5.2.2.
- 2. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications,"
February 1991. GRAND GULF B 3.3-213 urncR B043 Page 65 of 197
Editorial: delete extra underlines CRFA System Instrumentation B 3.3.7.1 to return to the standard format BASES spacing ACTIONS B.1 With the required action and completion time not met, the associated isolation dampers must be closed. This effectively establishes the isolation made of CRFA operation. The 1-hour completion time is intended to *allow the operator time to establish this mode of operation. It is acceptable because it minimizes risk while allowing time to establish the CRFA subsystem in operation. SURVEILLANCE The Surveillance is also modified by a Note to indicate REQUIREMENTS that when a channel is placed in an ,inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains CRFA System initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. SR 3.3.7.1.1 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.7.3, "Control Room Fresh Air (CRFA) System," overlaps The Surveillance this Surveillance to provide complete testing of the assumed Frequency is safety function. controlled under the Surveillance
- conditions that apply during a plant Frequency Control outage and tho potential for an unplanned transient if tho Program. ~uruoillanco Hero performed uith tho reactor at pouor.
Operating experience has shot1n those components usually pass tho ~uruoillanco uhon performed at tho 24 month Frequency (continued) GRAND GULF B 3.3-217 LBl;fCR BQ4s Page 66 of 197
LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE SR 3.3.8.1.1 (continued) REQUIREMENTS The FreE!uenoy of 31 days is based on plant operating The Surveillance oxperienoe Pith regard to ohannel gp:ggngILITY and drift that ' Frequency is demonstrates that failure of more than one ohannel of a giuen Funotion in any 31 day interual is rare. controlled under the Surveillance Frequency Control SR 3.3.8.1.2 and SR 3.3.8.1.3 "-!,.. Program. A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive The Surveillance calibrations consistent with the plant specific setpoint Frequencies are methodology. controlled under the Surveillance Frequency Control Program. SR 3 . 3 . 8 . 1. 4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed in The Surveillance LCO 3~8.1 and LCO 3.8.2 overlaps this Surveillance to Frequency is provide complete testing of the assumed safety functions. controlled under the
- Surveillance auruoillanoe under the oonditions that apply during a plant Frequency Control outage and the potential for an unplanned transibnt if tho Program. aurueillanoe uere performed uith the reaotor" at pouer, Operating experienoe has sho\1n these oomponents usually pass the aurueillanoe uhen performed at tho 24 month FroE!uenoy "-"
REFERENCES 1. UFSAR, Section 8. 3 .1.
- 2. UFSAR, Section 5. 2.
- 3. UFSAR, Section 6. 3.
- 4. UFSAR, Chapter 15.
(continued) GRAND GULF B 3.3-231 UU>CR BQ4j Page 67 of 197
RPS Electric Power Monitoring B 3.3.8.2 BASES ACTIONS If any Required Action and associated Completion Time of Condition A or
- B are not met in MODE 4 or 5, with any control rod withdrawn from a core cell containing one or more fuel assemblies, the operator must immediately initiate action to fully insert all insertable control rods in core cells containing one or mar~ fuel assemblies (Required Action D.1 ). This Required Action results in the least reactive condition for the reactor core and ensures that the safety function of the RPS (e.g., scram of control rods) is not required. All actions must continue until the applicable ~*, ,
Required Actions are completed. SURVEILLANCE SR 3.3.8.2.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is performed on each overvoltage, undervoltage, and underfrequency channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. " As noted in the Surveillance, the CHANNEL FUNCTIONAL TEST is only required to be performed while the plant is in a condition in which the loss of the RPS bus will not jeopardize steady state power operation (the design of the system is such that-the power source must be removed from service to conduct the Surveillance). The 24 hours is intended to indicate an outage of sufficient duration to allow for scheduling and proper performance of the Surveillance. The 184 etay l=Feet1:1enoy anet the Note in the Surveillance afe based on guidance provided in Generic.Letter 91-09, The Surveillance (Ref. 3). ~ . r-;---, Frequency is ~
....__,,,71"" * ~
controlled under the SR 3.3.8.2.2 Surveillance Frequency Control. CHANNEL CALIBRATION is a complete check of the instrument loop and Program. . the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument The Surveillance drifts between successive calibrations consistent with the plant specific Frequency is setpoint methodology. controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.3-237 LBDGR 1404@ Page 68 of 197
RPS Electric Power Monitoring B 3.3.8.2 BASES SURVEILLANCE SR 3.3.8.2.3 REQUIREMENTS (continued) Performance of a system functional test demonstrates a required system actuation (simulated or actual) signal. The discrete relays/logic of the system will automatically trip open the associated power monitoring assembly circuit breaker. Only one signal per power monitoring assembly is required to be tested. This Surveillance overlaps with the CHANNEL
- CALIBRATION to provide complete testing of the safety function. The system functional test of the Class 1E circuit breakers is included as part of this test to provide complete testing of the safety function. If the The Surveillance breakers are incapable of operating, the associated electric power
, Frequency is monitoring assembly would be inoperable. . controlled under the Surveillance The 24 month FFDquenoy is eased on the neeel to t3erform *this Frequency Control Sunmillanoe under the oonditions that aJ313ly durin§I a J3lant 01:1ta§e and the J3otential for an unJ3lanned tran~ient if the Surveillanee t.uere 13eriormed Program.
*1..*ith the roaster at J30'Ner. OJ3eratin§ mEJ3erienoe has shown that these OOR1f30Rents USl:Jally f)aSS the Surveillanoe \Vhen J3erformed at the .
24 month Frequeney. REFERENCES 1. FSAR, Section 8.3.1.1.5.
- 2. NEDC-32988-A, Re~ision 2, Technical Justification to Support Risk- 'k Informed Modification to Selected Required End,States for BWR I" Plants, December 2002.
- 3. NRC Generic Letter 91-09, "Modification of Survemance Interval for "1' the Electric Protective Assemblies in Power Supplies for the Reactor Protection System."
GRAND GULF B 3.3-239 LBDGR 14943 Page 69 of 197
SURVEILLANCE Rf outaEMtNr:s
,;~T!UI~,trt;t{/f~rf~flt~m~
- 1vAii! :r]~t;tt:i 7.~~~1~, f.µ~,
1 9 f )Q%. .of .rated
- core. {:low) ,
- the MCPR t'eguJr~m*en:ts p.MV::fde_
lar\ger' rnarg,*ns to the fue:l ;'cl adding thtegritY. Safe*ty: tt'mit
.sfrch: fha*t the potentiil adVeh;e effect :,O_f e~rly hotlth,\f:
.ttafi~it1op :during:~: ~OCA -is redu~ed_. - A. l~rg:~r flo0. rriJ*s.111~tPh
- c~n *t~e:r~Jore; _be. alJOW§Q }Jhen; co.re: f]9W' f$ ~ }Q% 9} *- rale.d :_ .*_
0 cptei flow*: The. rec_ircu lat.ion; Joop_. det pump; :tlow, _,~si iis:etd'. dn thi,s*:$*urveifla'ri¢e,_ . is. t:b<= summatiqh cof' ~p,e:*fJpws::fr:o)H.* ?1::1 -oJ
},It~ j~,t pu_rrips. 'a?\os}~tid :wj~lt :a s}n9.l;ijr feitr9y'1_al;;1:;t{6;.:1}9p~ -
Th~ *mi.$m_alc:h *ts mea.s.µre:d ~tn. ter_rn_s: *9f perq~ni: .qf r:crf:~g t:OJ\e flow~ th{s
- Surveill<fnce can '.he me't by veri fyhig:: tha't the,
- reci fculat+on loop dr'*i ve *fl ow mi smatCh ,: when. twd loffps 'ci'r~e
- p dpera'ti on; is *<- $% , 6J rf) te.d re,cj rcuJ}tJpn dr.j ve
- fl.6_.wi ~(th c,or:e;_, flow*: ~.*: °? 0% of r'a;t-ed ,co re . fl ow an-cf <, tb'*% of'. rated - . .
- r*~_ci:rGUli:l"tlQ.D" driv:e: f.i~w wi"th CQre* f'lo:w**-*~---.- 70%(.o.f i*ated t:CJjr.'e*
fl:ow:. Thts ;~'.~ ts.- not *refqyi.ref1. wh~h **b9th lo.ops ~*f~ . }i~t. 'in\pp;¢"rc1'J1:p)l The Surveillance .sinc.e.;th~ mismat.ch limit~. are._me.ani:rig'l~:,~:s durj;ng*1 singJ~e;loo*p* Frequency is or. natural circ.ul a-tion '.op.er at ion.. Th:e ;s*urveil la*nce must .h,{ controlled under the ,' erforme~d wHHirJ .24 hoqrs aft.er' bot:h'. Too1i$ a.rre: .i ri .iop_~taJ'tqb:. Surveillance , ,-__ *.,.. ~Qur fr"¢que:,19cy i? e*a19~J~tel'lt 'oH{~' 'lkE; Fle,qu~\9e:k *t~r - Frequency Control Je:t .f3.UffiP .OP E'.RABlL_ITY~ ve I" ,-{ic atf efl. --~.:rre ha.s ~eefl, sl~.t:i)Yfl ~,:
- 13,1?e1~a'tfi9§ e.*x~el"fe~ee.:. i:e, be e;de~uat*~ '"te. d@:l~eJ, :e_ff 6euri~J i~t, Program.
- ~tlffl~ reep fle~1s. ii~ a 1'i~m~lf fi'1a1~nei - ~.
GRAND: .GDl F Page 70 of 197
FCVs B 3.4.2 BASES ACTIONS* (continued) lf'the FCVs are not deactivated (locked up) and ,cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 12 hours. This brings the unit to a condition where the flow coastdown characteristics of the recirculation loop are not important. The allowed Completion Time of 12 hour~ is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and with-out challenging unit systems. SURVEILLANCE SR 3.4.2.1 REQUIREMENTS Hydraulic power unit pilot operated isolation valves located between the servo valves and the common "open" and "close" lines are required to close in the event of a loss of hydraulic pressure. When closed, these valves inhibit FCV motion by blocking hydraulic pressure from the servo valve to the common open and close lines as well as to the alternate The Surveillance subloop. This Surveillance verifies FCV lockup on a loss of hydraulic F~equency is pressure. controlled under the Surveillance* Frequency Control thisSurveillanee uneler the eonelitions that apply eluring a plant outage anel Program. the potential for an unplanneel transient if the. Surveillanee 'Nore perforFReet v,ith the roaster at pm.var. Operating e>Eperienee has shm.vn these eoFRponents usually pass the SR ,.:vhen porforFRed at the 24 FRonthrrequoney. Therefore, tho Froquoney 'Nos oonolueloel to so aeeoptaele froFR a reliaeility standpoint.
-+-
SR 3.4.2.2 The Surveillance This SR ensures the overall average rate of FCV movement at all Frequency is positions is maintained within the analyzed limits. controlled under the Surveillance Tho 24 FRonth Froetueney is eased on the nooel to porforFR thisSurvoillaneo unaor tho eonditions that apply eturing a plant outage and Frequency Control the potential for an unplanneet transient if the Program. (continued) GRAND GULF B 3.4-11 , LBDGR 1ao4a Page 71 of 197
FCVs 8 3.4.2 BASES SURVEILLJ\~JGE SR a.4.2.2 (continued) REQUIREME~JTS - Surveillance *.vere performed *.uith the reactor at po*Ner. Operatin~ mcperienee has shown these components usually pass the SR '1..'hen performed at the 24 month Frequency. Therefore, the Frequency waseoneluded to be aeeeptable from a reliability standpoint. REFERENCES 1. UFSAR, Section 15.3.2.
- 2. UFSAR, Section 15.4.5.
GRAND GULF 8 3.4-12 Page 72 of 197
Jet Pumps B 3.4.3 BASES (continued) SURVEILLANCE SR 3.4.3.1 REQUIREMENTS This SR is designed to detect significant degradation in jet pump performance that precedes jet pump failure (Ref. 2). This SR is required to be performed only when the loop has forced recirculation flow since surveillance checks and measurements can only be performed during jet pump operation. The jet pump failure of concern is a complete mixer displacement due to jet pump beam failure. Jet pump plugging is also of concern since it adds flow resistance to the recirculation loop. Significant degradation is indicated. if the specified criteria confirm unacceptable
*deviations from established patterns or relationships. The allowable deviations from the established patterns have been developed based on the variations experienced at plants during normal operation and with jet pump assembly failures (Refs. 2 and 3). Since refueling activities (fuel assembly replacement or shuffle, as well as any modifications to fuel support orifice size or core plate bypass flow) can affect the relationship between core flow, jet pump flow, and recirculation loop flow, these relationships may need to be re-established each cycle. Similarly, initial entry into extended single recirculation loop operation may also require establishment of these relationships. During the initial weeks of operation under such conditions, wh511 - - - ining new "established patterns,"
engineering judgment oft e fflffl'J' urveillance results is used to detect significant abnormalities w
- Id indicate a jet pump failure.
The recirculation flow control valve (FCV) operating characteristics (loop flow versus FCV position) are determined by the flow resistance from the loop suction through the jet pump nozzles. A change in the relationship indicates a flow restriction; loss in pump hydraulic performance, leak, or new flow path between the recirculation pump discharge and jet pump nozzle. For this criterion, the loop flow versus FCV position relationship must be verified. Total core flow can be determined from measurements of the recirculation loop drive flows. Once this relationship has been established, increased or reduced tota(core flow for the same recirculation loop drive flow may be an indication of failures in one or several jet pumps. (continued) GRAND GULF B 3.4"15 Re dsi6H ~~8. 9 . Page 73 of 197
- J:~t ~:P.nti?"~)
13 :~\If\.~{
- 'Sl:JRV,EtLliAN'GE:,,
*:Ret1Qt1{~*Mg'~J-:Sf The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
~~'.a~~t~:J;'.~).t*~i~~:;mtti§~ ~it:t:~l N§..r \~}q,- ... ~~t .:e:y.fup ;~~ij~_;
**~~!l:ij~i~i~.ff~b.;ij3~~$W~*l~~f &~vi~ijl,tfMt'@':, ~w&:
a: j'(4~16: Page 74 of 197
S/RVs B 3.4.4 BASES SURVEILLANCE SR 3.4.4.1 (continued) REQUIREMENTS lift settings must be performed during shutdown, since this is a bench test, and in accordance with the INSERVICE TESTING PROGRAM. The ~ lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures. The safety lift setpoints will still be set within a tolerance of \:J 1 percent, but the setpoints will be tested to within \:J 3 percent to determine acceptance or failure of the as-found valve lift setpoint. If a valve is tested and the lift setpoint is found outside the 3 percent tolerance, two additional valves are to be tested (Reference 4). The Frequency was selected because this Surveillance must be performed during shutdown conditions and is based on the time between refuelings. SR 3.4.4.2 The required relief function S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to verify the mechanical portions of the automatic relief function operate as designed when initiated either by an actual or simulated initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in The Surveillance SR 3.3.6.5.4 overlaps this SR to provide complete testing of the safety Frequency is function. controlled under the * ~ .
- Surveillance Tl=lo 24 ~eRth FreetueRsy is eases on the Reeel to r:>erferm tt=..s Frequency Control Surveillanee uRder the eonditioAs that apply auriR§ a plant 01:Jta§e aRa the Program. potential for an l:JRplaRRea transient if tl=le S1.:Jrveillanee *..veFO J30Ffor1T10Ei witl=l tl=le reaetor at ;:>O':Jer. Operatin§ mcperienee !=las sl=lovm .these OOfRf30AORts 1::1sually pass tt:,e SR when perforFRea at t!=10 24 FAOAtR FFOEfueney. Therefore, tt:le Freql:Jeney v.*as oonelbleleet to be aeeeptable froFA a reliaeility standpoint.
This SR is modified by a Note that excludes valve actuation. This prevents an RPV pressure blowdown. SR 3.4.4.3 A manual actuation of each required S/RV (those valves removed and replaced to satisfy SR 3.4.4.1) is performed to (continued} GRAND GULF B 3.4-20 u:mcR 1ao10 Page 75 of 197
RCS Operational LEAKAGE B 3.4.5 BASES ACTIONS C.1 and C.2 (continued) 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from .full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.4.5.1 REQUIREMENTS The RCS LEAKAGE is monitored by a variety of instruments designed to quantify the various types of LEAKAGE. Leakage detection instrumentation is discussed in more detail in the Bases for LCO 3.4.7, The Surveillance "RCS Leakage Detection Instrumentation." Sump level is typically Frequency is monitored to determine actual LEAKAGE rates. However, any method controlled under the may be used to quantify LEAKAGE within the guidelines of Reference 7. Surveillance In eonjuRetioR *.vith alarffls aAa other aetFRinistrative eoAtrols, a 12 t=lour Frequency Control FreetueAey for this SurveillaRee is ar:,13repriate for iaentifyiR~ ehanges in Program. LEAKAGE ans for traol<iAg mquiFOe! trends (Ref. 8). REFERENCES 1. 10 CFR 50.2.
- 2. 10 CFR 50.55a(c).
- 3. 10 CFR 50, Appendix A, GDC 55.
- 4. GEAP-5620, "Failure Behavior in ASTM A 1068 Pipes Containing Axial Through c Wall Flaws," April 1968.
- 5. NUREG-75/067, "Investigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of Boiling Water Reactor Plants,"
October 1975.
- 6. UFSAR, Section 5.2.5.5.3.
- 7. Regulatory Guide 1.45, May 1973 with exceptions per UFSAR Appendix 3A. *
& Genoris LeMer SS 01, Supf:)lement 1, "NRG Pssitien en IGSGC in*
BW-R A~stenitie Stainless Steel Piping," Fesruary 1992. GRAND GULF B 3.4-26 LDC 99988 Page 76 of 197
RCS Leakage Detection Instrumentation B 3.4.7 BASES ACTIONS (continued) samples, are sufficient to alert the operating staff to an unexpected increase in unidentified LEAKAGE. The 12 hour interval is sufficient to detect increasing RCS leakage. The Required Action provides 7 days to restore another RCS leakage monitor to OPERABLE status to regain the intended leakage detection diversity. The 7 day Completion Time ensures that the plant will not be operated in a degraded configuration for a lengthy time period. E:1 and E.2 With both the gaseous and particulate drywell atmospheric monitor channels and the drywell air cooler condensate flow rate monitor inoperable, the only means of detecting LEAKAGE is the drywell floor drain sump monitoring system. This Condition does not provide the required diverse means of leakage detection. The Required Action is to restore eit~er of the inoperable monitoring systems to OPERABLE status within 30 days to regain the intended leakage detection diversity. The 30 day Completion Time ensures that the plant will not be operated in a degraded configuration for a lengthy time period. F.1 and F.2 If any Required Action of Condition A, B, C, D, or E cannot be met within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions in an orderly manner and without challenging plant systems. G.1 With all required monitors inoperable, no required automatic means of monitoring LEAKAGE are available, and immediate plant shutdown in accordance with LCO 3.0.3 is required. , ( SURVEILLANCE: SR 3.4.7.1 REQUIREMENTS This SR requires the performance of a CHANNEL CHECK of the required The Surveillance drywell atmospheric monitoring system. The check gives reasonable confidence that the channel is operating properly. The FFOE1UOAeyef Frequency is
--:) 12 AOl:JFS is easeeJ OR iRstruFRent reliability and is feasonaele f.or aeteeting controlled under the off normal conditions:
Surveillance (continued) Frequency Control Program. GRAND GULF B 3.4-36 UU)CR 119~8 Page 77 of 197
RCS Leakage Detection Instrumentation B 3.4.7 BASES SURVEILLANCE REQUIREMENTS (continued) SR 3.4.7.2 This SR requires the performance of a CHANNEL FUNCTIONAL TEST of The Surveillance the required RCS leakage detection instrumentation. The test ensures Frequency is that the monitors can perform their function in the desired manner. The controlled under the test also verifies the relative accuracy of the instrumentation. =l=Re Surveillance Ffee;weney of a1 says eonsideFS instruR=tent reliability, and oporatin~ Frequency Control mEperienee l=tas shown it proper fof detesting ao§fadation. Program. (continued) GRAND GULF B 3.4-36a hHDCR 11868 Page 78 of 197
RCS Leakage Detection Instrumentation B 3.4.7 BASES SURVEILLANCE SR 3.4.7.3 REQUIREMENTS (continued) This SR requires the performance of a CHANNEL CALIBRATION of the The Surveillance required RCS leakage detection instrumentation channels. The calibration* Frequency is verifies the accuracy of the instrumentation, including the instruments controlled under the ~ located inside the drywell. The Frequency of 24 FAonths is a Surveillance typiealreJuoling eyele and eonsideFS ohannel reliaeility. Opemting OXf)OFiORGO Ras ~F0¥0A tt:lis FFequensy is QGGOJ:)taele.
\
Frequency Control Program. REFERENCES 1. 10'CFR 50, Appendix A, GDC 30.
- 2. Regulatory Guide 1.45, Revision 0, "Reactor Coolant Pressure Boundary Leakage Detection System." May 1973.
- 3. GEAP-5620, "Failure Behavior in ASTM A 1068 Pipes Containing Axial Through c Wall Flaws," April 1968.
- 4.
- NUREG-75/067, "Investigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of Boiling Water Reactor Plants,"
October 1975.
- 5. UFSAR, Section 5.2.5.5.3.
- 6. UFSAR, Section 5.2.5.2.
GRAND GULF 8 3.4-37 LBDGR. 12043 Page 79 of 197
RCS Specific Activity B 3.4.8 BASES (CO".ltinued) SURVEILLANCE SR 3.4.8.1 REQUIREMENTS This Surveillance is performed to ensure iodine remains within limit during The Surveillance normal operation. The 7 day FFequoney is a~equate to trona ohan§es in Frequency is the iodine aotivity level. controlled under the Surveillance This SR is modified by a Note that requires this Surveillance to be Frequency Control performed only in MODE 1 because the level of fission products Program. generated in other MODES is much less. REFERENCES 1. 10 CFR 50.67, AAccident Source Term.-@-
- 2. UFSAR, Section 15.6.4.
GRAND GULF B 3.4-41 LDC 919§9 Page 80 of 197
RHR Shutdown Cooling System - Hot Shutdown B 3.4.9 BASES ACTIONS 8.1, 8.2, and 8.3 (continued) separately for each occurrence involving a loss of coolant circulation. Furthermore, verification of the functioning of the alternate method must be reconfirmed every 12. hours thereafter. This will provide assurance of continued .temperature monitoring capability. I During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling system or recirculation pump), the reactor coolant temperature and pressure must be periodically monitored to ensure proper function of the alternate method. The once per hour Completion Time is deemed appropriate. SURVEILLANCE SR 3.4.9.1 REQUIREMENTS This Surveillance verifies that one RHR shutdown cooling subsystem or The Surveillance recirculation pump is in operation and circulating reactor coolant. The Frequency is required flow rate is determined by the flow rate necessary to provide controlled under the sufficient decay heat removal capability. The FrequeRey af 12 t:lours is Surveillance su#ieieAt in vie\v of other *,isual aAa audible indications a*,ailable to u~c Frequency Control operator for monitoriA§ the RHR subsysteFA iR the eantrol room. Program. This Surveillance is modified by a Note allowing sufficient time to align the RHR System for shutdown cooling operation after clearing the pressure interlock that isolates the system, or for placing a recirculation pump in
. operation. The Note takes exception to the requirements of the Surveillance being met (i.e., forced coolant circulation is not required for this initial 2 hour period), which also allows entry into the Applicability of this Specification in accordance with SR 3.0.4 since the Surveillance will not be "not met" at the time of entry into the Applicability.
SR 3.4.9.2 RHR Shutdown Cooling System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR shutdown cooling system subsystems and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel. Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of (continued) GRAND GULF B 3.4-46 LBDGR 14044 Page 81 of 197
I RHR Shutdown Cooling System - Hot Shutdown B 3.4.9 BASES important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions. The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume,at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Shutdown Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. RHR Shutdown Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative subset of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible
- locations where the maximum potential accumulated gas void volume has The Surveillance been evaluated and determined to not challenge system OPERABILITY.
Frequency is The accuracy of the method used for monitoring the susceptible locations controlled under the and trending of the results should be sufficient to assure system Surveillance OPERABILITY ~uring the Surveillance interval. Frequency Control Program. The This SR is modified by a Note that states the SR is not required to be Surveillance performed until 12 hours after reactor steam dome pressure is< [the RHR Frequency may vary cut in permissive pressure]. In a rapid shutdown, there may be insufficient by location time to verify all susceptible locations prior to entering the Applicability. susceptible to gas accumulation REFERENCES None. GRAND GULF B 3.4-46a LBDGR 14044 Page 82 of 197
RHR Shutdown Cooling System-Cold Shutdown B 3.4.10 BASES SURVEILLANCE SR 3.4.10.1 (continued) REQUIREMENTS determined by the flow rate necessary to provide sufficient decay heat removal capability. The FFequeney of 12 t=lours is su#ieieAt iR view of The Surveillance ott=ler visual and audielc iAdieations available to the 013cr=ator foF . Frequency is controlled fflonitoFin~ tt=ie RJ-4R subsystem in the control room. under the Surveillance Frequency* Control SR 3.4.10.2 Program. RHR Shutdown Cooling System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR shutdown cooling subsystems and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel. Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions. The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas atone or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Shutdown Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. RHR Shutdown Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion
*mechanisms*may be verified by monitoring a representative subset of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used (Continued}
GRAND GULF B 3.4-51 LBDCR 14044 Page 83 of 197
RHR Shutdown Cooling System-Cold Shutdown B 3.4.10 BASES SURVEILLANCE SR 3.4.10.2 (continued) REQUIREMENTS to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assure system OPERABILITY during the Surveillance interval. The 21 day Fre£1ueAey tal~es inte eonsideFatisn tl:ie ~radual nature af gas aeeumulatioA in the RrlR Shutdmrm Gaoling System pipiAg and the preeedural eentFOls geverning system operation. J \ REFERENCES None. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Surveillance Frequency may vary by location susceptible to gas accumulation GRAND GULF B 3.4-51a LBDGR 14044 Page 84 of 197
RCS PIT Limits B 3.4.11 BASES ACTIONS C.1 and C.2 (continued) Operation outside the PIT limits in other than MODES 1, 2, and 3 (including defueled conditions) must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses. The Required Action must be initiated without delay and continued until the limits are restored. Besides restoring the PIT limit'parameters to within limits, an evaluation is required to determine if RCS operation is allowed. This evaluation must
- verify that the RCPB integrity is a9ceptable and must be completed before approaching criticality or heating up to > 200EF. Several methods may be used, including comparison with pre-analyzed transients, new analyses, or inspection of the components. ASME Section XI, Appendix E (Ref. 6), may be used to support the evaluation; however, its use is restricted to evaluation of the beltline.
SURVEILLANCE SR 3.4.11.1 REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance ' Frequency Control rate ef ehan~e liFAits are speeifieel iA hm.1rly iRsreFReRts, ao FHinuteo Program. permits assessFRent and eorreetion of FRinor ~aviations. Surveillance for heatup and cooldown, or inservice leakage and hydrostatic testing may be discontinued when the criteria given in the relevant plant procedure for ending the activity are satisfied. This SR has been modified by a Note that requires this Surveillance to be performed only during system heatup and cooldown operations and inservice leakage and hydrostatic testing. (continued) GRAND GULF B 3.4-57 H_e7;isisft }1e. Q Page 85 of 197
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
' . - ' "'i;,. ,. *... : :, . .. : ~'
Page 86 of 197
.!srr .:'j\::4:/1:2L'f The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
;:};. **O,p$~iji siictJ6n: }t.:t.
*?>~. UFs}(Rt. S'~¢X"i*Ptr ts~.
Page 87 of 197
ECCS - Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.1 (continued) REQUIREMENTS susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system I OPERABILITY. The accuracy of the method used for monitoring the
- The Surveillance susceptible locations and trending of the results should be sufficient to Frequency is assure system OPERABILITY during the Surveillance interval.
controlled under the Surveillance The 21 say FFO~t::1eney is eased on operating eM19erienee, on tl=le Frequency Control 13roooetural oontrols governing systeFA ot3eration, ans on tho gFOaual Program. The nat1:JF0 of *,oia euilsup in the ~CGS 13iping. Surveillance Frequency may vary SR 3.5.1.2 by location Verifying the correct alignment for manual, power operated, and automatic susceptible to gas valves in the ECCS flow paths provides assurance that the proper flow accumulation. paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in *position since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve *
- manipulation; rather, it involves verification that those valves potentially capable of being mispositioned are in the correct position. This SR does The Surveillance not apply to valves that cannot be inadvertently misaligned, such as check Frequency is valves.
controlled under the Surveillance Frequency Control +ESTl~JG PROGRAM Feetuirements for perforFAing valve testing at least Program.
- onoo o*,eFy 92 elays. The Frequeney of 21 says is further justifies eeea1:1se tl=le valves aFe ot3eratea unser proeeaural sentrol ans aeoa1:Jse iFA13ro13er 'Jalve alignFAent wouls only a#oet a single subsysteFA. Tl=lis Freq~eney t=ias been sl=lewn to be aeeoptaale through operating ffi{f:)erioneo.
LPCI subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the RHR cut in permissive pressure in MODE 3, if capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. This allows operation in the RHR shutdown cooling mode during MODE 3 if necessary or alignment to allow for the operation of the ADHRS when MODE 4 is reached. {continued) GRAND GULF B 3.5-9 bi OCR 1e919 Page 88 of 197
ECCS - Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.2 (continued) REQUIREMENTS The Surveillance is modified by a Note which exempts system vent flow paths opened under administrative control. The administrative control should be proceduralized and include stationing a dedicated individual at the system vent flow path who is in continuous communication with the operators in the control room. This individual will have a method to rapidly close the system vent flow path if directed. SR 3.5.1.3 Verification every 21 says that ADS accumulator supply pressure is~ 150 psig assures adequate air pressure for reliable ADS operation. The accumulator on each ADS valve provides pneumatic pressure for valve actuation. The designed pneumatic supply pressure requirements for the accumulator are such that, following a failure of the pneumatic supply to the accumulator, at least two valve actuations can occur with the drywell at 70% of design pressure (Ref. 15). The ECCS safety analysis assumes The Surveillance only one actuation to achieve the depressurization required for operation Frequency is of the low pressure ECCS. This minimum required pressure of 150 psig controlled under the- is provided by the ADS Instrument Air Supply System. The 21 aay Surveillance FrequeRey takes iAte eeAsielemtioR aet1T1inistmti>.*e eoRtFsl oveF speration Frequency Control of the IRstrl:Jmont Air Su13J3ly Systeffl ans4llarms for low air f3FOGSl!lre. Program. SR 3.5.1.4 The performance requirements of the ECCS pumps are determined through application of the 10 CFR 50, Appendix K, criteria (Ref. 8). This periodic Surveillance is performed (in accordance with the ASME requirements (Ref. 19) for the ECCS pumps) to verify that the ECCS pumps will develop the flow rates required by the respective analyses. The ECCS pump flow rates ensure that adequate core cooling is provided to satisfy the acceptance criteria of 10 CFR 50.46 (Ref. 10). The pump flow rates are verified against a system head that is equivalent to the RPV pressure expected during a LOCA. The total system pump outlet pressure is adequate to overcome the elevation head pressure between the pump suction and the vessel discharge, the piping friction losses, ana RPV pressure present suring LOGAs. These values may be estaslist:loel eh:1ring pre 013erational testing. .'\. 92 etay FFOqueney fer U:iis Sl:lrveillanoe is in aoeei:aanee with the lnserviee Testing Program roquireffleRts. (continued) GRAND GULF 8 3.5-10 b9DGR 14944 Page 89 of 197
ECCS - Operating 8 3.5.1 BASES SURVEILLANCE SR 3.5.1.4 (continued) . REQUIREMENTS tosses, and RPV pressure present during LOCAs. These values may be established during pre-operational testing. The Frequency for this Surveillance is in accordance with the INSERVICE TESTING PROGRAM "'
. requirements.
SR 3.5.1.5 The ECCS subsystems are required to actuate automatically to perform their design functions. This Surveillance test verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of HPCS, LPCS, and LPCI will cause the systems or subsystems to operate as designed, including actuation of the system throughout its emergency operating sequence, automatic pump startup, and actuation of all automatic valves to their required positions. This Surveillance also ensures that the HPCS System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1, "Emergency Core Cooling System The Surveillance (ECCS) Instrumentation," overlaps this Surveillance to provide complete Frequency is testing of the assumed safety function. controlled under the Surveillance
~ Tl=lo 24 FROAth Freett:10Asy is l':lasea OR the noes to perforFR this SurveillaAeo uneler the eoRditions that apply dt:1ring a plaRt outage (mmept Frequency Control for Di*,ision Ill wl=lieh eaR ee testes in any eperotional eoAdition) and tl=m Program.
potential for an unplanned transient if the Surveillance were 13erformed with the roaster at power. Operating m~porienee has shown that these SOfFlf)Onents 1::1sblally pass tl=m SR v..*l=len J3eriorR-1ea at the 24 FRonth Fref:lueney, \"..'AieR is eased on the refueliR§ eyele. TherefeFe, tt=.e FFOqueney was ooneludea ta be aoeeptablo froFR a reliability standpoint. This SR is modified by a Note that excludes vessel injection/spray during
- the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.
(continued) GRAND GULF 8 3.5-11 LBDCR 1§91Q Page 90 of 197
ECCS - Operating 8 3.5.1
.BASES SURVEILLANCE SR 3.5.1.6 REQUIREMENTS
. (continued) The ADS designated S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to demonstrate that the mechanical portions of the ADS function (i.e.,
solenoids) operate as designed when initiated either by an actual or simulated initiation signal, causing proper actuation of all the required components. SR 3.5.1. 7 and the LOGIC SYSTEM FUNCTIONAL TEST The Surveillance performed in LCO 3.3.5.1 overlap this Surveillance to provide complete Frequency is testing of the assumed safety function. controlled under the Surveillance ~l'le 24 FReRtl'I FFeE!YBREl'J is Baseel eR ll'le Reeel ts 11eFfeFFR ll'lis Frequency Control Surveillanoe under the sonditions that app!y durin§ a plant outage and tho Program. potential for aR l:mp!annod transient if the Surveillanee-were t3ortormed* with the reactor at power. Ot3erating mcperionoe has st=te*.vn Umt those eeFR130nents usu.ally 13ass the SR when 19erf.orR=1eel at the 24 R=ionth Freet1:1enoy, ,.,vhieh is bases on the refueling eysle. TheFOfore, the Freetueney *.\'Os eoneh:.caea to ee aseeJ3taele fFoffi a reliasility standpoint. This SR is modified by a Note that excludes valve actuation. This prevents an RPV pressure blowdown. SR 3.5.1.7 A manual .actuation of each required ADS valve (those valves removed and replaced to satisfy SR 3,.4.4.1) is performed to verify that the valve is functioning properly. This SR can be demonstrated by one of two methods. If performed by method 1), plant startup is allowed prior to performing this test because valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements (Ref. 20), ~ prior to valve installation. Therefore, this SR is modified by a Note that states the Surveillance is not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. The 12 hours allowed for manual actuation after the required pressure is reached is sufficient to achieve stable conditions for testing and
* (continued)
GRAND GULF B 3.5-12 LBDGR 14Q43 Page 91 of 197
ECCS - Operating B 3.5.1
.*BASES ,
SURVEILLANCE SR 3.5.1.7 {continued) REQUIREMENTS alternately tested. The Frequency of the required relief-mode actuator testing was developed based on the tests required by ASME OM, Part 1, (Ref. 20) as implemented by the lnservice Testing Program of Specification 5.5.6. The testing Frequency required by the lnservice Testing Program is based on operating experience and valve performance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. SR 3.5.1.8 This SR ensures that the HPCS System response time is less than or equal to the maximum value assumed in the accident analysis. Specific testing of the ECCS actuation instrumentation inputs into the HPCS System ECCS SYSTEM RESPONSE TIME is not required by this SR. Specific response time testing of this instrumentation is not required since these actuation channels are only assumed to respond within the diesel generator start time; therefore, sufficient margin exists in the diesel generator 10 second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response without a specific measurement test (Ref. 17). The diesel generator starting and any sequence loading delays along with the Reactor Vessel Water Level - Low Low, Level 2 confirmation delay permissive must be added to the HPCS System equipment response times to obtain the HPCS System
- The Surveillance ECCS SYSTEM RESPONSE TIME. The acceptance criterion for the Frequency is HPCS System ECCS SYSTEM RESPONSE TIME is~ 32 seconds. "'
controlled under the Surveillance HPGS System EGGS SYSTEM RESPONSE TIME tests aFe eondueted
- Frequency Control every 24 FAORths. This Frequency is consistent with the ty;9ieal iRdustry Program. rdueling eyele and is based on industry 013eratin§ e*13erienee. '-*
(continued) GRAND GULF B 3.5-13a L~DGR 18072 Page 92 of 197
ECCS - Shutdown B 3.5.2 BASES (continued) SURVEILLANCE SR 3.5.2.1 and SR 3.5.2.2 I REQUIREMENTS The minimum water level of 12 ft 8 inches required for the suppression pool is periodically verified to ensure that the suppression pool will provide adequate net positive suction head (NPSH) for the ECCS pumps, recirculation volume, and vortex prevention. With the suppression pool water level less than the required limit, all low pressure ECCS subsystems are inoperable. HPCS is also inoperable if the low CST level suction swap to the suppression pool is enabled with suppression pool level less than the required limit. With the low CST level suction swap to the suppression pool disabled, H~CS is operable only if the CST level is> 18 ft. This level equates to a volume of approximately 169,000 gallons. Because of vortexing however, the usable volume will be less. At an indicated level of 18 ft with the suction swap disabled the usable volume will be approximately 137,000 gallons at 8175 gpm. This is sufficient volume to allow for operators time to attempt to terminate the inventory loss prior to fuel uncovery. There is no analytical basis for a specific CST volume requirement in response to a draindown event during shutdown. At an indicated level of 22 ft (low The Surveillance CST *alarm level) with the suction swap disabled the usable volume will be Frequencies are approximately 174,000 gallons at 8175 gpm. controlled under the Surveillance The. 12 hour Frequenoy of these SRs ,.:Jas de*,eloped eonsidering Frequency Control opemting experienee related to suppression pool ans CST water level Program. variations during the applicable MODES. Furthermore, the 12 t:iour Frequenoy is eonsidered adequate in viev..* of other indioations in the eantrel room, ineh:1ding alorR=Js, to alert the OJ:>erator to an alsnon=i=ial su13pression pool or CST *i.-..*ater level oondition. SR 3.5.2.3. SR 3.5.2.5. and SR 3.5.2.6 The Bases provided for SR 3.5.1.1, SR 3.5.1.4, and SR 3.5.1.5 are applicable to SR 3.5.2.3, SR 3.5.2.5, and SR 3.5.2.6, respectively. (continued) GRAND GULF B 3.5-18 LDC 96012 Page 93 of 197
ECCS - Shutdown B3.5.2 BASES
. SURVEILLANCE SR 3.5.2.4 (continued)
REQUIREMENTS initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does The Surveillance not require any testing or valve manipulation; rather, it involves verification Frequency is that those valves capable of potentially being mispositioned are in the controlled under the correct position. This SR does not apply to valves that cannot be Surveillance inadvertently misaligned, such as check valves. Tho 21 day Froql:4enoy is Frequency Control Program. In MODES 4 and 5, the RHR System may operate in the shutdown cooling mode, or be aligned to allow alternate means to remove decay heat and sensible heat from the reactor. Therefore, RHR valves ithat are required for LPCI subsystem operation may be aligned for decay heat removal. One LPCI subsystem of the RHR System may be considered OPERABLE for the ECCS function if all the required valves in the LPCI flow path can be manually realigned (remote or local) to allow injection into the RPV and the system is not otherwise inoperable. This will ensure adequate core cooling if an inadvertent vessel draindown should occur. The Surveillance is modified by a Note which exempts system vent flow
.paths opened under administrative control. The administrative control should be proceduralized and include stationing a dedicated individual at the system vent flow path who is in continuous communication with the operators in the control room. This individual will have a method to rapidly close the system vent flow path if directed.
(continued} GRAND GULF B 3.5-19 L9DGR 14044 Page 94 of 197
RCIC Sys,tem B 3.5.3 BASES (continued) SURVEILLANCE SR 3.5.3.1 REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control SR 3.5.3.2 Program. The Surveillance Verifying the correct alignment for manual, power operated, and Frequency may vary automatic valves in the RCIC flow path provides assurance that the by location proper flow path will exist for RCIC operation. This SR does not apply to susceptible to gas valves that are locked, sealed, or otherwise secured in position since accumulation. these were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as The Surveillance check valves. For the RCIC System, this SR also includes the steam flow Frequency is path for the turbine and the flow controller position. controlled under the Surveillance Frequency Control TESTl~JG PROGR.'\M requireFRonts for 1:>erforming *.mlve testing at least Program. every 92 says. Tl=le FFequeney ef 21 etays is R:Jrtt"ier justifioet seeause the
\'ah:es are eperatod ~meter prooee!ural eentrol and booauso iml:)FO~eF .
\'alve position v.*ould affost only the RGIG System. This Froquensy has seen she*..*:n te ee aooeptaelo through eperatiAg mcporioAee.
The Surveillance is modified by a Note which exempts system vent flow paths opened under administrative control. The administrative control should be proceduralized and include stationing a dedicated individual at the system vent flow path who is in continuous communication with the operators in the control room. This individual will have a method to rapidly close the system vent flow path if directed. (continued) GRAND GULF B 3.5-24a t:BDGR 1§910 Page 95 of 197
RCIC System
. 83.5.3 BASES SURVEILLANCE SR 3.5.3.3 and SR 3.5.3.4 REQUIREMENTS (continued) The RCIC pump flow rates ensure that the system can maintain reactor coolant inventory during pressurized conditions with the RPV isolated.
The flow tests for the RCIC System are performed at two different pressure ranges such that system capability to provide rated flow is tested both at the higher and lower operating ranges of the system. Additionally, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure when the RCIC System diverts steam flow. Since the required reactor steam pressure must be available to perform SR 3.5.3.3 and SR 3.5.3.4, sufficient time is allowed after adequate pressure and flow are achieved to perform these SRs. Reactor startup is allowed prior to performing the low pressure Surveillance because the reactor pressure is low and the time to satisfactorily perform the Surveillance is short. The reactor pressure is allowed to be increased to normal operating pressure since it is assumed that the low pressure test has been satisfactorily completed and there is no indication or reason to believe that RCIC is inoperable: Therefore, these SRs are modified by Notes that state the Surveillances The Surveillance ar~ not required to be performed until 12 hours after the reactor steam Frequency is pressure and flow are adequate to perform the test. controlled under the Surveillance A 92 day Frequency f.or SR 3.6.3.3 is eonsistont 'Nith the l~JSERVIGE ..J._ Frequency Control TESTING PROGRAM Fequiroments. The 24 FAonth FFOquenoy for SR I" Program. a.a.3.4 is eases en tl=le need to perrorm this SurveillaRee unaer the eonditions that apply just prior to or during startup woFR a plant outage. Opemting ex;.;,erieneo has sho*:vn U:mt these oomponents usually pass tho
~ROA ;3erforA=1eel at tRe 24 FAontt=t Freet1:eenoy, *.vhioh is easeel en the refueling eyole. TheFOfuFO, the Frequenoy *:..*as eeneludod to so
-aeoeptable ffOFA a roliability staneiJ:)oint.
SR 3.5.3.5 The RCIC System is required to actuate automatically to perform its
. design function. This Surveillance verifies that with a required system initiation signal (actual or simulated) the automatic initiation logic of RCIC will cause the system to operate as designed, including actuation of the system throughout its emergency. operating sequence,
{continued) GRAND GULF B 3.5-25 LBDGR 16010 Page 96 of 197
RCIC System B 3.5.3 BASES SURVEILLANCE SR 3.5.3.5 (continued) REQUIREMENTS automatic pump startup and actuation of all automatic valves to their required positions. This Surveillance test also ensures that the RCIC System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System The Surveillance lnstrum,entation," overlaps this Surveillance to provide complete testing of Frequency is the assumed safety function. controlled under the Surveillance Frequency Control &rvoillanee under the eonditions that apply during a plant ol:ftage and the Program. 13otential for an unplanned transient if the Survcillanee \Vere peoorFRed with the reaetor at pov.'or. O,sorating C*t=)OFionso t:las sRo'NA that tl=lese eofflponents usually pass the SR when performed at the 24 FAonth '}.. Frequency, 'Nhieh is based on the refueling syele. Therefore, the FreE1uenoy *..*,as eoneluaeet to be aeeeptab!e froffl a reliaei!ity standpoint. This SR is modified by a Note that excludes vessel injection during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.
* .REFERENCES 1. 10 CFR 50, Appendix A, GDC 33.
- 2. UFSAR, Section 5.4.6.2.
- 3. Memorandum from R. L. Baer (NRC) to V. Stello, Jr. (NRC),
"Recommended Interim Revisions to LCO's for ECCS Components," December 1, 1975.
GRAND GULF B 3.5-26 LBDGR 1204a Page 97 of 197
Primary Containment Air Locks B 3.6.1.2 BASES ACTIONS D.1 and D.2 (continued) does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.1.2.1 \.1 REQUIREMENTS Maintaining primary containment air locks OPERABLE requires compliance with the leakage rate test requirements of 10 CFR 50, Appendix J (Ref. 2), as modified by approved exemptions. This SR reflects the leakage rate testing requirements with regard to air lock leakage (Type B leakage tests). The leakage rate testing requirements include the airlock test connection valves (Type C leakage tests). The periodic testing requirements verify that the air lock leakage does not exceed the allowed fraction of the overall primary containment leakage rate. The SR has been modified by two Notes. Note 1 states that an inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. This is considered reasonable since either air lock door is capable of providing a fission product barrier in the event of a DBA. Note 2 has been added to this SR, requiring the results to be evaluated against the acceptance criteria of SR 3.6.1.1.1. This ensures that air lock leakage is properly accounted for in determining the overall primary containment leakage rate. Since the overall primary containment leakage rate is only applicable in MODES 1, 2, and 3 operation, the Note 2 requirement is imposed only during these MODES. SR 3 . 6. 1. 2 . 2 The seal air flask pressure is verified to be at~ 90 psig ij ij~s 7 ~~ss to ensure that the seal system remains viable. It must be checked because it could bleed down during or (continued) GRAND GULF B 3.6-11 LDC Q§Q44 Page 98 of 197
Primary Containment Air Locks B 3.6.1.2 BASES SURVEILLANCE SR 3.6.1.2.2 (continued) REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. SR 3.6.1.2.3 The air lock interlock mechanism is designed to prevent simultaneous opening of both doors in the air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident primary containment pressure (Ref. 3), closure of either door will support primary containment OPERABILITY. Thus, the interlock feature supports primary containment OPERABILITY while the air lock is being used for personnel transit in and out of the containment. Periodic testing of this interlock demonstrates that the interlock will function as The Surveillance Frequency is controlled under the Surveillance door is 1:1sed for entry and mdt (proood1:1ros roq1:1ire striot Frequency Control adhoronoo to single door opening), this test is only Program. req1:1irod to be performed every 24 months. The 24 month Freq1:1enoy is based on the need to perform this £1:1rr.roillanoo under oonditions that apply d1:1ring a plant 01:1tago, and tho potential for loss of primary oontainmont gpggng11IT¥ if tho
£1:1ruoillanoo uas performed uith tho roaotor at pouor. ~
24 month Froq1:1onoy for tho intorlook is j1:1stified based on gonerio operating experienoe. Tho 24 month Froq1:1enoy is based on engineering judgment and is oonsiderod adeq1:1ato gi:uen that the interlook is not ohallonged d1:1ring the 1:100 of the airlook. ( continued) GRAND GULF B 3.6-12 LDC 99Q§Q Page 99 of 197
Primary Containment Air Locks B 3.6.1.2
/
SURVEILLANCE SR 3 . 6 . 1. 2 . 4 REQUIREMENTS (continued) A seal pneumatic system test to ensure that pressure does not decay at a rate equivalent to> 2 psig for a period of 48 hours from an initial pressure of 90 psig is an The Surveillance effective leakage rate test to verify system performance. Frequency is controlled under the ~tJ.prgillaH.o@ uaQH. porfonaod at tao 2 4 HWH.ta Froqt1onoy, Surveillance \Taioa is basod on tag roft1oliBg oyelo. Taerefore, tao Frequency Control Froqt10H.ey uas e0Belt1ded to be aeeeptable from a reliability Program. standpoiH.t, 1 REFERENCES 1. UFSAR, Section 3.8.
- 2. 10 CFR 50, Appendix J.
- 3. UFSAR, Table 6.2-13.
GRAND GULF B 3.6-13 LDDCR138B Page 100 of 197
PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.1 (continued) REQUIREMENTS purge valves are capable of closing in the environment following a LOCA. Therefore, these valves are allowed to The Surveillance be open for limited periods of time. Tao ;n day Fro~l:loBoy Frequency is controlled under the Surveillance Frequency Control SR 3.6.1.3.2 Program. This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment, drywell, and steam tunnel, and not locked, sealed, or otherwise secured and is required to be closed during accident conditions, is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the primary containment boundary is within design limits. This SR does not require any testing or valve manipulation. Rather, it involves verification The Surveillance that those devices outside primary containment, drywell, Frequency is and steam tunnel, and capable of being mispositioned, are controlled under the in the correct position. aiBoo verifioatieB ef ualuo Surveillance relatively easy, tao prouide Frequency Control added assl:lraBoo taat Program. positioBo. Two Notes are added to this SR. The first Note applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these devices, once they have been verified to be in the proper position, is low. A second Note is included to clarify that PCIVs open under administrative controls are not required to meet the SR during the time the PCIVs are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing. (continued) GRAND GULF B 3.6-22 LDC 999§Q Page 101 of 197
PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.5 REQUIREMENTS (continued) For primary containment purge valves with resilient seals, additional leakage rate testing beyond the test The time based requirements of 10 CFR 50, Appendix J (Ref. 3), is required Surveillance to ensure OPERABILITY. Operating experience has demonstrated that this type of seal has the potential to Frequency is degrade in a shorter time period than do other seal types. controlled under the Surveillance maintaining this penetration leak tight (duo to tho direct Frequency Control path botuoon primary containi:Hont and tho onuiroFHRont) , a Program. Fro~1.:1onoy of ~ '3 )months, r1ith oonsidoration giuon to operational oxporionoo and safety signifioanoo Additionally, this SR must be performed for all purge valves within 92 days following any purge valve failing to meet it's acceptance criteria. This ensures that any common mode seal degradation is identified. is
!"Once within 92 day"I- - - , \
T~Frequency for this a~ accordance with the INSERVICE TESTING PROGRAM as is modified by a note that indicates that all valves do not have to be retested due to the failure of another valve, prbvided they have been tested within 92 days prior to any valve failing to meet it's acceptance criteria. The SR is modified by a Note stating that the primary containment purge valves are only required to meet leakage rate testing requirements in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, purge valve leakage must be minimized to ensure offsite 1 radiological release is within limits. At other times when the purge valves are required to be capable of closing (e.g., during handling of recently irradiated fuel), pressurization concerns are not present and the purge valves are not required to meet any specific leakage criteria. SR 3 . 6. 1. 3 . 6 Verifying that the full closure isolation time of each MSIV
-is within the specified limits is required to demonstrate OPERABILITY. The full closure isolation time test ensures that the MSIV will isolate in a time period that does not (continued)
GRAND GULF B 3.6-24 Page 102 of 197
PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.7 (continued) REQUIREMENTS PCIV will actuate The Surveillance Frequency is controlled under the Surveillance Frequency Control a1:1ruoillaBoo uora porforHiod r1ith tho roaotor at pouor, OperatiB~ experiaBoo has sho,1B that those oompoBonts Program. 1:1s1:1ally pass this gypreillaBoo uhoB porformod at tho 2 4 moBth Froq1:10Boy, Thorofore, tho Freq1:10Boy uaa 00Bol1:1dod to be aoooptabla from a roliability standpoiBt. SR 3 . 6. 1. 3 . 8 The analyses in Reference 2 is based on leakage that is less than the specified leakage rate. Leakage through any single main steam line must bes 100 scfh when tested at a pressure of 11.9 psig. Leakage through all four steam lines must bes 250 scfh when tested at Pa (11.9 psig). The MSIV leakage rate must be verified to be in accordance with the leakage test requirements of Reference 3, as modified by approved exemptions. A Note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2 and 3. In the other conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required. SR 3.6.1.3.9 Surveillance of hydrostatically tested lines provides assurance that the calculation assumptions of Reference 2 is met. This SR is modified by a Note that states these valves are only required to meet the combined leakage rate in MODES 1, 2, and 3 since this is when the Reactor Coolant System is (continued) GRAND GULF B 3.6-25 LllDCR 13 Q4A Page 103 of 197
Primary Containment Pressure B 3.6.1.4 BASES ACTIONS 8.1 and B.2 (continued) required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3. 6. 1. 4.1 REQUIREMENTS Verifying that primary containment to auxiliary building differential pressure is within limits ensures that The Surveillance operation remains within the limits assumed in the primary Frequency is containment analysis. The 12 ha~r Fre~Meney af tkis SR,}<<§ controlled under the devel apaa based ai, aJH~~rat i fl§ experi eRee relstea ts tr-eAa i~ Surveillance primary eafltainmeAt pressij~e vsri&tieRs ~Hrifl§ the appli eaal a MODES. F1n*thermaioe, the 12 hear Fre(it:1eAey is Frequency Control eeAsiaered adeqijate iR view af ether iRaieatiefls available Program.
- in the eantrel raam, inelijdiftg alarms, ta alert the speratar ta aA al3Aarma1 primary ceRtai AmeAt pressl:Jv-e eeruJi tier:;.
REFERENCES 1. UFSAR, Section 6.2.1.
- 2. UFSAR; Section 6.2.1.1.4.2.
- 3. UFSAR, Section 6.2.
GRAND GULF B 3.6-28 Rev hi en Na. e Page 104 of 197
Primary Containment Air Temperature B 3.6.1.5 BASES SURVEILLANCE SR 3.6.1.5.1 (continued) REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control inoludin~ alarms, to alert tho operator to an Program. primary oontainmont air temperature oondition. REFERENCES 1. UFSAR, Section 6.2. GRAND GULF B 3.6-31 R-e. isisR }Js. l Page 105 of 197
LLS Valves B 3.6.1.6 BASES SURVEILLANCE SR 3.6.1.6.1 (continued) REQUIREMENTS The successful performance of the test sample of S/RVs provides
*reasonable assurance that the remaining installed S/RVs will be perform in a similar fashion. After the S/_RVs are replaced, the electrical and pneumatic connections shall be verified either through mechanical/electrical inspection or test prior to the resumption of electric power generation to ensure that no damage has occurred to the S/RV during transportation and installation. This verifies that each replaced S/RV will properly perform its intended function.
The STAGGERED TEST BASIS Frequency ensures that both solenoids for each LLS valve relief-mode actuator are alternatively tested. The Frequency of the required relief-mode actuator testing is based on the tests required by ASME OM Part 1 (Ref. 3), as implemented by the lnservice Testing Program of Specification 5.5.6. The testing Frequency required by the lnservice Testing Program is based on operating experience and valve performance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. (Reference 4) SR 3.6.1.6.2 The LLS designed S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to verify that the mechanical portions (i.e., solenoids) of the automatic LLS function operate as designed when initiated either by an actual or simulated automatic initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.5.4 overlaps this SR to provide complete The Surveillance testing of the safety function. Frequency is controlled under the Surveillance SurveillaRee under the eonetitions that at3t9ly during a J3lant outage and the Frequency Control J3otential for an uRplanned transient if the Sl:.lrveillanee weFO perforFAeet Program. with the roaster at pov:er. Operating m<t9eriense has shown these components usually pass the SurveillaRoe \.Vhen 130Fformod at the 24 month Frequency. TheFOf.ore, tt:10 Free;ueney was eoAeluded to ee aooeptable from a reliability standpoint. This SR is modified by a Note that excludes valve actuation. This prevents a reactor pressure vessel pressure blowdown. REFERENCES 1. GESSAR-11, Appendix 38, Attachment A, Section 3BA.8.
- 2. FSAR, Section 5.2.2.2.3.3.
- 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
- 4. ASME Code for Operation and Maintenance of Nuclear Power Plants, Part 1.
- 5. GNRl-96/00229, Amendment 130 to the Operating License.
GRAND GULF B 3.6-35 LBDCR 14943 \ Page 106 of 197
RHR Containment Spray System B 3.6.1.7 BASES SURVEILLANCE SR 3.6.1.7.1 (eoRtinuod) REQUIREMENTS wo Notes have been added to this SR. The first Note allows RHR Verifying the correct containment spray subsystems to be considered OPERABLE during alignment for manual, alignment to and operation in the RHR shutdown cooling mode when power operated, and below the RHR .cut in permissive pressure in MODE 3, if capable of being automatic valves in manually realigned and not otherwise inoperable. At these low pressures the RHR containment and decay heat levels (the reactor is shut down in MODE 3), a reduced spray mode flow path complement of subsystems should provide the required containment provides assurance pressure mitigation function thereby allowing operation of an RHR that the proper flow shutdown cooling loop when necessary. The s,econd Note exempts paths will exist for system vent flow paths opened under administrative control. The system operation. administrative control should be proceduralized and include stationing a This SR does not dedicated individual at the system vent flow path who is in continuous apply to valves that communication with the operators in the control room. This individual will are locked, sealed, or have a method to rapidly close the system vent path if directed. otherwise secured in position, since these SR 3.6.1.7.2 were verified to be in RHR Containment Spray System piping and components have the the correct position potential to develop voids and pockets of entrained gases. Preventing prior to locking, and managing gas intrusion and accumulation is necessary for proper sealing, or securing. operation of the RHR suppression pool spray subsystems and may also This SR does not prevent water hammer and pump cavitation. Selection of RHR . require any testing or Containment Spray System locations susceptible to gas accumulation is valve manipulation; based on a review of system design information, including piping and rather, it involves instrumentation drawings, isometric drawings, plan and elevation
- verification. that those drawings, and calculations. The design review is supplemented by valves capable of* system walk downs to validate the system high points and to confirm the being mispositioned location and orientation of important components that can become are in the correct sources of gas or could otherwise cause gas to be trapped or difficult to position. This SR remove during system maintenance or restoration. Susceptible locations does not apply to depend on plant and system configuration, such as stand-by versus valves that cannot be operating conditions.
inadvertently - The RHR Containment Spray System is OPERABLE when it is sufficiently misaligned, such as filled with water. Acceptance criteria are established for the volume of check valves. accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible The Surveillance location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas .volume at the suction or Frequency is discharge of a pump), the Surveillance is not met. If it is determined by controlled under the subsequent
- Surveillance Frequency Control continued Program.
GRAND GULF B 3.6-39 1.BDGR 14044-Page 107 of 197
RHR Containment Spray System B 3.6.1.7 BASES SURVEILLANCE SR 3.6.1.7.2 (continued) REQUIREMENTS evaluation that the RHR Containment Spray System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. RHR Containment Spray System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative subset of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations The Surveillance and trending of the results should be sufficient to assure system Frequency is OPERABILITY during the Surveillance interval. controlled under the Surveillance The 21 day Froe;ueney talms into eonsisorotion the gradual nature of gas Frequency Control aeeumulation iA tl=le Rl=IR GoAtainment S19ray SystoFR piraing ana the Program. The prooedural oontrols governing systeFA 019eratien. Surveillance
- Frequency may vary SR 3.6.1.7.3 by location Verifying eachRHR pump develops a flow rate~ 7450 gpm while susceptible to gas operating in the suppression pool cooling mode with flow through the accumulation associated heat exchanger ensures that pump performance has not degraded below the required flow rate during the cycle. It is tested in the pool cooling mode to demonstrate pump OPERABILITY without spraying down equipment in primary containment. Flow is a normal test of centrifugal pump performance required by the ASME Code, Section XI (Ref. 2). This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the INSERVICE TESTING PROGRAM. ""
(continued) GRAND GULF B 3.6-40 LBDCR 1§Q1Q Page 108 of 197
RHR Containment Spray System B 3.6.1.7 BASES SURVEILLANCE SR 3.6.1.7.4 REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control with the roaster at power. Operating mEpcrienoe has sho*.vn that those Program. eofflpenents l::lsually pass the Surv:eillanee when perrormed at tt:,e 24 fflOnth FFOEfl:JOAey. Theref-OFO, tRO FFOE;l:JOAey was eonell:Jeteet to BO aeeeptable from a reliability standpoint. SR a.a.1.7.e and TRM SR a.S.1.7.1 The following survcmanees are performed to defflonstFate the CoRtaiAment S13ray SysteFR roFAaiRs uAobstrueted and oapable of f.lowin*g 'Nater '.tv'Ren requires. Tl=le testin~ 13raotioes anel free;ueneies (as diseussed belo'N) are adequate to demonstrate ttm system \Nill perforFA as required. SR 3.6.1.7.5 This surveillance is performed to verify the spray nozzles are not obstructed. This surveillance may be accomplished by verifying the nozzle opehings are free of material that would obstruct the flow of water or the performance of an air flow test through each nozzle. The type of testing utilized should be based on system operating history and the .availability of the appropriate testing equipment. UFSAR Section 6.2.2.2 (Reference 3) defines preoperational The Surveillance Frequency is testing performed on the system, which is not required to be controlled under the duplicated by the performance of this surveillance testing. The 1O Surveillance year rrequenoy is aelequate to detest degradation in perfurFRanoe Frequency Control due to the passhm Rozzle design and its norR=mlly df)* state and has Program. beeA shown to be aoeeptas!e through industry operating e*perieRoe. (continued) GRAND GULF B 3.6-40a L9DGR 1§93s Page 109 of 197
FWLCS B 3.6.1.8 BASES (continued) ACTIONS C.1 (continued)
'1 Required Action C.1 is modified by a Note that states that LCO 3.0.4.a is not applicable when entering MODE 3. This Note prohibits the use of LCO 3.0.4.a to enter MODE 3 during startup with the LCO not met.
However, there is no restriction on the use of LCO 3.0.4.b, if applicable, because LCO 3.0.4.b requires performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering MODE 3, and establishment of risk management actions, if appropriate. LCO 3.0.4 is not applicable to, and the Note does not preclude, changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. The allowed Completion Time is reasonable, based on operating ~ experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.1.8.1 REQUIREMENTS Proper operation of the RHR jockey pump is required to verify the The Surveillance capability of the FWLCS to provide sufficient sealing water to each Frequency is isolated section of each feedwater line to initiate and maintain the fluid controlled under the seal for long term leakage control. Tl=te 31 eJay FFe~t:JeRey is eoRsideFed Surveillance Frequency Control Program. REFERENCES 1. FSAR, Section 15.6.5.
- 2. NEDC-32988-A, Revision 2, Technical Justification to Support Risk Informed Modification to Selected Required End States for BWR t
Plants, December 2002. GRAND GULF B 3.6-43 LBDCR 14Q43 Page 110 of 197
MSIVLCS B 3.6.1.9 BASES ACTIONS (continu~d) If the MSIV LCS subsystem cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a t MODE in which overall plant risk is minimized. To achieve this status, the ~ plant must be brought to at least MODE 3 within 12 hours. Remaining in the Applicability of the LCO is acceptable because the plant risk in MODE 3 is similar to or lower than the risk in MODE 4 (Ref. 4) and because the time spent in MODE 3 to perform the necessary repairs to restore the system to OPERABLE status will be short. However, voluntary entry into MODE 4 may be made as it is also an acceptable
* ,ow-risk state.
Required Action C.1 is modified by a Note that states that LCO 3.0.4.a is not applicable when entering MODE 3. This Note prohibits the use of LCO 3.0.4.a to enter MODE 3 during startup with the LCO not met. However, there is no restriction on the use of LCO 3.0.4.b, if applicable, because LCO 3.0.4.b requires performance of a risk assessment . addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering MODE 3, and establishment of risk management actions, if appropriate. LCO 3.0.4 is not applicable to, and the Note does not preclude, changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. The allowed Completion. Times is reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.1.9.1 REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.6-46 LBDCR 11913 Page 111 of 197
MSIVLCS B 3.6.1.9 BASES SURVEILLANCE REQUIREMENTS SR 3.6.1.9.2 (continued) Deleted SR 3.6.1.9.3 A system functional test is performed to ensure that the MSIV LCS will operate through its operating sequence. This includes verifying that the automatic positioning of the valves and the operation of each interlock The Surveillance and timer are correct, that the blowers start and develop the required flow Frequency is rate and the necessa~ vacuu~. The 24 FAonth Freq~_eney is based on controlled under the Surveillance auring a plant outa§e ana U=1e potential for an unplanneel transient if tl=m Frequency Control Surveillanee were performed *..vitR the reaetor at 19ower. Operatin~ Program. eM13erienoe has shown that these eoFA13onents usually pass the Surveillanee when 13erforR-md at the 24 month Frequeney. TheFOfoFe, the Fre(:11:1enoy 'tJas eonoluaea to ee aese13taele freffi a relial:>ility standpoint. REFERENCES 1. FSAR, Section 6. 7 .1.
- 2. FSAR, Section 15.6.5.
- 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk '}
Informed Modification to Selected Required End States for BWR Plants, December 2002. GRAND GULF B 3.6-47 lsIU>CR 14 Q 43 Page 112 of 197
Suppression Pool Average Temperature B 3.6.2.l BASES ACTIONS E.l and E.2 (continued) basis maximum allowable values for primary containment temperature or pressure. SURVEILLANCE SR 3 . 6 . 2 . 1. 1 REQUIREMENTS The suppression pool average temperature is regularly monitored to eniure that the required limits are satisfied. The Surveillance Average temperature is determined by taking an arithmetic Frequency is average of the functional suppression pool water temperature controlled under the channels. Tho 24 hoYr Froqyonoy has boon sho\1n to be Surveillance aoooptablo based on operating mrporionoo. When heat is being added to the suppression pool by testing, however, it Frequency Control is necessary to monitor suppression pool temperature more Program. frequently. The 5 minute Frequency during testing is justified by the rates at which testing will heat up the suppression pool, has been shown to be acceptable based on operating experience, and provides assurance that allowable pool temperatures are not exceeded. The
- further justified in view of other indications the control room, including alarms, to alert th operator to an abnormal suppression pool average temperatur condition.
REFERENCES 1. UFSAR, Section 6.2. 5 minute
- 2. UFSAR, Section 15.2. Frequency is GRAND GULF B 3.6-52 Re.isi8H Ne. 9 Page 113 of 197
Suppression Pool Water Level B 3.6.2.2 BASES ACTIONS B.1 and B.2 (continued) If suppression pool water level cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.2.2.1 REQUIREMENTS the suppression The Surveillance Frequency is controlled under the Surveillance Frequency Control the applioable D40DE:a and to assessinrg: the proxiFHity to the speoifiod LCO level liFHits. E"':t:irtherFHoro, the 2 4 hour Program. Frequenoy is oonsidered adequate in :uieH of other indioations auailable in the oontrol room., inoh1ding alarFHs, to alert the operator to an abnorm.al suppression pool Hater level Gondition. REFERENCES 1. UFSAR, Section 6.2.
- 2. ER 97/0089-00-00, ECCS Suction Strainer Installation.
GRAND GULF B 3.6-55 LDC 97Q74 Page 114 of 197
RHR Suppression Pool Cooling B 3.6.2.2 BASES SURVEILLANCE SR 3.6.2.3.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves, in the RHR suppression pool cooling mode flow path provides assurance that the proper flow path exists for system* operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these valves were verified to be in the correct position prior to being locked, sealed, or secured. A valve is also allowed to be in the nonaccident position, provided it can be aligned to the accident position within the time assumed in the accident analysis. This is acceptable, since the RHR suppression pool ~ooling mode is manually initiated. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being The Surveillance mispositioned are in the correct position. This SR does not apply to Frequency is valves that cannot be \nadvertently misaligned, such as check valves. controlled under the Surveillance Frequency Control unaer proeedural eontrol, improper valve position \'vould affeet only a Program. single subsystem, the probability of an event requiring initiation of the system is low, and the subsystem is a IT'lanually initiated systern. This F'requeney has been shovm to be aeeeptable, based ori operating experienee. SR 3.6.2.3.2 RHR Suppression Pool Cooling System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR suppression pool cooling subsystems and may also prevent water hammer and pump cavitation. Selection of RHR Suppression Pool Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings; isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions. The RHR Suppression Pool Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas GRAND GULF B 3.6-59 LBDGR 14044 Page 115 of 197
RHR Suppression Pool Cooling . B 3.6.2.2 BASES SURVEILLANCE SR 3.6.2.3.2 {continued) REQUIREMENTS is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Suppression Pool Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. RHR Suppression Pool Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative subset of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations The Surveillance and trending of the results should be sufficient to assure system Frequency is OPERABILITY during the Surveillance interval. controlled under the Surveillance Frequency Control Program. The Surveillance SR 3.6.2.3.3 Frequency may vary by location Verifying each RHR pump develops a flow rate~ 7450 gpm, with flow susceptible to gas through the associated heat exchangers to the suppression pool, ensures accumulation. that pump performance has not degraded during the cycle. Flow is a normal test of centrifugal pump performance required by ASME Section XI (Ref. 2).-J This test confirms one point on the pump design curve, and the results are indicative of overall performance. Such inservice ~ inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance*. The Frequency of this SR is in accordance with the INSERVICE TESTING 'h PROGRAM. GRAND GULF B 3.6-59a LBDGR 1a010 Page 116 of 197
SPMU System B 3.6.2.4 BASES ACTIONS B.1 (continued) Therefore, the upper containment pool water temperature must be restored to within limit within 24 hours. The 24 hour Completion Time is sufficient to restore the upper containment pool to within the specified temperature limit. It also takes into account the .low probkbility of an event occurring that would require the SPMU System. C.1 With one SPMU subsystem inoperable for reasons other than Condition. A or B, the inoperable subsystem must be restored to OPERABLE status within 7 days. The 7 day Completion Time is acceptable in light of the redundant SPMU System capabilities afforded by the OPERABLE subsystem and the low probability of a DBA occurring during this period. D.1 and D.2 If any Required Action and required Completion Time cannot be met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to 1 at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.2.4.1 REQUIREMENTS The upper containment pool water level is regularly The Surveillance monitored to ensure that the required limits are satisfied. Frequency is The 24 hour Frequeney of this aR vas developed, eonsidering controlled under the operating oxporioneo rol~tod to upper eontainment pool r.1ator louol variations during tho applieablo ~4QQ:i;;;:£ and Surveillance considering tho lou probability of a mm occurring botuoon Frequency Control suruoillancos Furthermore, tho 2 4 hour Froqum:1cy is Program. considered adequate in uiou of other indications available in tho control room, ineluding alarms, to alert tho operator to an abnormal upper containment pool water leuel condition (continued) GRAND GULF B 3.6-63 Re. isieH }Je. e Page 117 of 197
SPMU System B 3.6.2.4 BASES SURVEILLANCE SR 3.6.2.4.2 REQUIREMENTS (continued) The upper containment pool water temperature is regularly monitbred to ensure that the required limit fs satisfied. The Surveillance Frequency is controlled under the during tho applicable MODEa. Surveillance Frequency Control SR 3.6.2.4.3 Program. Verifying the correct alignment for manual, power operated, and automatic valves in the SPMU System flow path' provides assurance that the proper flow paths will exist for system operation. This SR does not apply to valves that are locked, sealed, or oth~rwise secured in position, since these valves are verified to be in the correct position prior to being locked, sealed, or secured. This SR does not require any testing or valve manipulation. Rather, it involves verification that those valves capabl~ of potentially being mispositioned are in the correct The Surveillance position. This SR does not apply to valves that' cannot be Frequency is in~dvertently misaligned, such as check valves. controlled under the Surveillance because improper Frequency Control subsysto:r:ri. ~ Program. Frequency has through operating m~porionco. SR 3.6.2.4.4 The upper containment pool has two gates used to separate the pool into distinct sections to facilitate fuel transfer and maintenance during refueling operations and two additional gates in the separator pool weir wall extension, which, when installed, limit personnel exposure and ensure adequate water submergence of the separator when the separator is stored in the pool. The SPMU System dump line, penetrations are located in the steam separator storage section of the pool. To provide the required SPMU System dump volume to the suppression pool, the gates must be removed (or placed in their stored position) to allow communication between the various pool'sections. The Surveillance is modified by a Note that allows leaving (continued) GRAND GULF B 3.6-64 LDC 9~996 Page 118 of 197
SPMU System B 3.6.2.4 BASES SURVEILLANCE SR 3.6.2.4.4 (continued) REQUIREMENTS the gates installed if the Suppression Pool Low Thevel limit is increased to 18 ft' 5 1/ 12 inches. ( See Reference 3) . The Surveillance Frequency is controlled under the Surveillance Frequency Control The provision to allow gate installation in MODES 1, 2, and 3 results in isolating a portion of the SPMU System dump Program. volume. This provision does not apply to the separator pool weir wall extension gates. These gates are not readily accessible with the upper containment pool at its required level. Supporting analyses have shown that increasing the minimum suppression pool level adequately compensates for water trapped by isolating the fuel storage and/or fuel transfer canal areas. SR 3.6.2.4.5 This SR requires a verification that each SPMU subsystem automatic valve actuates to its correct position on receipt of an actual or simulated automatic initiation signal. This includes verification of the correct automatic positioning of the valves and of the operation of each interlock and timer. As noted, actual makeup to the The Surveillance suppression pool may be excluded. The LOGIC SYSTEM Frequency is FUNCTIONAL TEST in SR 3.3.6.4.6 bverlaps this SR to provide controlled under the complete testing of the safety function. Tho 24 ffionth Surveillance Froquono:y is bQ.sod on tho need to perform this guruoillanoo under tho oonditions that apply durin~ a plant outa~o and Frequency Control tho potential for an unplanned transient if tho Program. guruoillanoo rrnro performed r1ith tho roaotor at pouor. Oporatin~ 01icporionoo has shmm that those omapononts usually pass tho guruoillanoo .uhon performed at tho 24 month Froquonoy. Therefore, tho Froquonoy uao oonoludod to be aoooptablo froffi a reliability standpoint. This SR is modified by a NOTE that excludes makeup to the suppression pool. Since all active components are. testable, makeup to the suppression pool is not required. ( continued) GRAND GULF B 3.6-65 LBDCR lJQB Page 119 of 197
Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES (continued) SURVEILLANCE SR 3.6.3.2.1 and SR 3.6.3.2.2 REQUIREMENTS These SRs verify that there are no physical problems that could affect the igniter operation. Since the igniters are mechanically passive, they are not subject to mechanical failure. The only credible failures are lo 9 s of power or burnout. The verification that each required igniter is The Surveillance energized is performed by circuit current versus voltage Frequencies are measurement. controlled under the Surveillance The Frequeney of 1@ 4 days has been shmm to be aeeeptable through operating e.2..perienee beeause of the loH failure Frequency Control oeeurrenee, and provides aoouranee that hydrogen burn Program. eapability mdsts betueen the Hlore rigorous 1@ Ffl:onth 25urveillanees. Operating mcperienee has ohoun these 00H1:ponents usually pass the 25urueillanee uhen perforHied at a 1@4 day Frequeney. Additionally, these surveillaneeo Hlust be perforHied every 92 days if four or Ffl:ore ignitero in any division are inoperable. The 92 day Frequeney uas ehosen, reeognieing that the failure oeeurrenee is higher than norHlal. Thus, deereasing the Frequency froffi 184 days to 92 days is a prudent Hl:eaoure, sinee only one more inoperable igniters (for a total of five) uill result in an inoperable igniter division. SR 3.6.3.2.2 is modified by a Note that indicates that the Surveillance is not required to be performed until 92 days after four or more igniters in the division are discovered to be inoperable. SR 3.6.3.2.3 and SR 3.6.3.2.4 These functional tests are performed every lQ ~onths to verify system OPERABILITY. The current draw to develop a I surface temperature of z 1700EF is verified for igniters in inaccessible areas, e.g., in a high radiation area. The Surveillance Additionally, the surface temperature of each accessible Frequencies are igniter is measured to be z 1700EF to demonstrate that a controlled under the temperature sufficient for ignition is achieved. Surveillance 25ur:ueillanco uhen perforFfl:od at tho 24 Ffl:onth Frequeney. Frequency Control Thoroforo, tho Froqueney uao eoneluded to be aeeoptablo Program. froHl a reliability standpoint. ( continued) GRAND GULF B 3.6-76 Page 120 of 197
Drywell Purge System B 3.6.3.3 BASES ACTIONS B.1 and B.2 (continued) provided by one division of the hydrogen igniters. The 1 hour Completion Time allows a reasonable period of time to verify that a loss of hydrogen control function does not exist. The verification may be performed as an administrative check by examining logs or other information to determine the availability of the alternate hydrogen control system. It does not mean to perform the surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control system. If the ability to perform the hydrogen control function is maintained, continued - operation is permitted with two drywell purge subsystems inoperable for up to 7 days. Seven days is a reasonable time to allow two drywell purge subsystems to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of an accident. C.l If any Required Action and associated Completion Time cannot be met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours. The allowed Completion Time of 12 hours is reasonable, based on operati,ng experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.3.3.1 REQUIREMENTS Performance of a CHANNEL FUNCTIONAL TEST demonstrates the The Surveillance associated channel will function properiy. Any.setpoint Frequency is adjustment shall be consistent with the assumptions of the controlled under the plant specific setpoint methodology. The 31 day Surveillance Frequency Control Program. SR 3.6.3.3.2 Operating each drywell purge subsystem from the control room for~ 15 minutes ensures that each subsystem is OPERABLE and (continued) GRAND GULF B 3.6-81 LBDCR 1293§ Page 121 of 197
Drywell Purge System B 3.6.3.3 BASES SURVEILLANCE SR 3.6.3.3.2 (continued) REQUIREMENTS that all associated controls are functioning properly. It The Surveillance also ensures that blockage, compressor failure, or Frequency is excessive vibration can be detected for corrective action. controlled under the Surveillance Frequency Control Program. SR 3.6.3.3.3 Operating each is The Surveillance Frequency is maintaining drywell controlled under the flammability limit. Surveillance a plant outage uhon tho dryuoll boundary is Frequency Control not required. Operating 02{:porionco has shmm that those Progr,am. qompononts usually pass tho aur:uoillanco Hhen porforH-1od at tho 24 H-lonth Frequency Therefore, tho Frequency Pas concluded to be acceptable froH-1 a reliability standpoint. SR 3 .. 6. 3 . 3 . 4 This SR verifies that the pressure differential required to open the vacuum breakers is~ 1.0 psid and that the isolation valve differential pressure actuation instrumentation opens the valve at 0.0 to 1.0 psid (drywell The Surveillance minus containment). This SR includes a CHANNEL CALIBRATION Frequency is of the isolation valve differential pressure actuation controlled under the
- nstrumentation. Operating experience has shorn:~ that those Surveillance components usually pass tho auruoillanco uhon performed at tho 24 H-lonth Frequency. Therefore, tho Frequency Has Frequency Control concluded to be acceptable froH-1 a reliability standpoint.
Program. REFERENCES 1. Regulatory Guide 1.7, Revision 1.
- 2. UFSAR, Section 6.2.5.
- 3. Technical Specification Amendment 145 to GGNS Operating License.
GRAND GULF B 3.6-82 UH)Cg l§QlQ Page 122 of 197
Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.1 and SR 3.6.4.1.2 (continued) REQUIREMENTS, The Surveillance Frequen9ies are controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF B 3.6-86a LDC 99959 Page 123 of 197
Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.3 and SR 3.6.4.1.4 (continued) REQUIREMENTS , these SRs is to ensure that the SGT subsystem, being used for the test, functions as designed. There is a separate LCO 3.6.4.3 with Surveillance Requirements which serves the primary purpose of ensuring
- OPERABILITY of the SGT system. SRs a.e.4.1.a and a.e.4.1.4 need not be perf.ormeel v,ith eaeh SGT subsystem. The SGT subsystem useel for these Surveillanees is sta§§ereel to ensure that in aelelition to the The Surveillance reetuirements of LGO a.e.'4 .a, either SGT subsystem *..viii perform this test.
Frequencies are The inoperability of the SGT system does not necessarily constitute a controlled under the failure of these Surveillances relative to the secondary containment Surveillance ~?PERABILITY. Operatin§ mEperienee has shown the seoonelary Frequency Control eontainment boundaf)' usl:lally passes these Smveillanees when Program. perf.ormeel at the 24 R1onth Freetueney. Therefore, the Freetueney *..vas eonoluded to be aeeeptable from a r_oliaeility stanelpoint. REFERENCES 1. UFSAR, Section 15.6.5.
- 2. UFSAR, Section 15.7.4.
- 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk Informed Modification to Selected Required End States for BWR Plants, December 2002.
GRAND GULF B 3.6-87a LBDCR 1490 Page 124 of 197
SCIVs B 3.6.4.2 BASES ACTIONS C.l and C.2 (continued) reasonable,.based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. D.l and D.2 '+,.. If any Required Action and associated Completion Time cannot be met, the plant must be placed in a condition in which the LCO does not apply. If applicable, the movement of recently "f.. irradiated fuel assemblies in the primary and secondary containment must be immediately suspended. Suspension of these activities shall not preclude completion of movement of a component to a safe position. Also, if applicable, action must be immediately initiated to suspend OPDRVs in order to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. Required Action D.l has been modified by a Note stating that LCO 3.0.3 is not applicable. If moving recently irradiated ~ fuel assemblies while in MODE 4 or 5, LCO 3.0.3 would not specify any action. If moving recently irradiated fuel 'i-... assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations. Therefore,, in either case, inability to suspend movement of recently irradiated 1' fuel assemblies would not be a sufficient reason to require a reactor shutdown. SURVEILLANCE' SR 3.6.4.2.1 REQUIREMENTS This SR verifies each secondary containment isolation manual valve, damper, rupture disk, and blind flange that is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases .outside of the secondary containment boundary is within design limits. This,SR does not require any testing or SCIV manipulation. Rather, it involves verification that those SCIVs in secondary The Surveillance containment that are capable of being mispositioned are in Frequency is the correct position. controlled under the Surveillance Frequency Control Program. (continued) GRAND GULF LDC 999§1
SC IVs B 3.6.4.2 BASES SURVEILLANCE SR 3.6.4.2.1 (continued) REQUIREMENTS relatively easy, the 31 day Frequenoy Has ohosen to provide added assuranoe that the aCIVs are in the oorreot positions. Two Notes have been added to this SR. The first Note applies to valves, dampers, rupture disks, and blind flanges located in high radiation areas and allows them to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these SCIVs, once they have been verified to be in the proper position, is low. A second Note-has been included to clarify that SCIVs that are open under administrative controls are not required to meet the SR during the time the SCIVs are open. SR 3.6.4.2.2 Verifying the isolation time of each power operated, automatic SCIV is within limits is required to demqnstrate OPERABILITY. The isolation time test ensures that the SCIV will isolate in a time period less than or equal to that assumed in the safety analyses. Generally, SCIVs must close within 120 seconds to support the functioning of the Standby Gas Treatment System. SCIVs may have analytical closure times based 6n a fur'iction other than se_condary containment isolation, in which case the more restrictive time applies. The Frequency of this SR is in accordance with the INSERVICE ""-l. TESTING PROGRAM. I' SR 3.6.4.2.3 Verifying that each automatic SCIV closes on a secondary containment isolation signal is required to prevent leakage of radioactive material from secondary containment following a DBA or other accidents. This SR ensures that each automatic SCIV will actuate to the isolation position on a secondary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.6 overlaps this SR to provide complete testing of the safety function. The 24 ffionth (continued) GRAND GULF B 3.6-94 LBDCR 1§010 Page 126 of 197
SCIVs B 3.6.4.2 BASES SURVEILLANCE SR 3.6.4.2.3 (continued) REQUIREMENTS The Surveillance Frequency is controlled under the performed Hith the roaster at pouer. Surveillance Operating eE.perienoe has shown these oomponents usually Frequency Control pass the aurueillanoe uhen performed at the 24 "ffionth Frequenoy.* Therefore, the Frequeno:y uas oonoluded to be Program. aooeptable from a reliability standpoint. REFERENCES 1. UFSAR, Section 15.6.5.
- 2. UFSAR, Section 6.2.3.
- 3. UFSAR, Section 15.7.4.
GRAND GULF B 3.6-95 LBDCR 13Q43 Page 127 of 197
SGT System B 3.6.4.3 BASES ACTIONS D.1 (continued) Required Action. D.1 is modified by a Note that states that LCO 304a is not applicable when entering* MODE 3. This Note prohibits the use of LCO 304a to enter M9DE 3 during startup with the LCO not met. However, there is no restriction on the use of LCO 304b, if applicable, I beca~se LCO 304b requires performance of a risk assessment
*addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering MODE 3, and establishment of risk management actions, if appropriate LCO 304 is not applicable to, and the Note does not preclude, changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the .unit.
The allowed Completion Time is reasonable, based on operating experience, to reach the required plant conditions from full power
- cond~tions in an orderly manner and without challenging plant systems. -
E.1andE.2 / When two SGT subsystems are inoperable, if applicable, movement of recently irradiated fuel assemblies in the primary and secondary containment must be immediately suspended. Suspension of these activities shall not preclude completion of movement of a component to a safe position. Also, if applicable, actions must be immediately* initiated to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until OPDRVs are suspended. SURVEILLANCE SR 3.6.4.3.1 REQUIREMENTS Operating each SGT subsystem from the control room for ~ 15 continuous hours ensures that both subsystems are OPERABLE and that The Surveillance all associated controls are functioning properly. It also ensures that Frequency is blockage, fan or motor failure, or excessive vibration can be detected for controlled under the corrective action. T~e d1 day l=FeEtt:Jenoy *.vas developed in oonsidemtion 1 Surveillance of the lmm:m reliabi lity of fun motoFS and eontmls and the Fedt:Jndanoy Frequency Control available in the system. Program. SR 3.6.4.3.2 This SR verifies that the required SGT filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The VFTP includes t~sting HEPA filter performance, charcoal adsorber efficiency, minimum.,system flow,rate, and the physical properties of the activated charcoal (general use and following specific operations). {continued. GRAND GULF B 3.6-100 LBDCR 1eQ7~ Page 128 of 197
SGT System B 3.6.4.3 BASES SURVEILLANCE SR 3.6.4.3.2 (continued) REQUIREMENTS Specific test frequencies and additional information are discussed in detail in the VFTP. SR 3.6.4.3.3 The SR requires verification that each SGT subsystem starts upon recipt The Surveillance of an actual or simulated initiation signal. Frequency is controlled under the . The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.6 overlaps this Surveillance SR to provide complete testing of. the safety function. V'Jhile this. Frequency Control . Program. mcperience has shown these coFAponents usually pass the Surveillance
'Nhen peoorFAeei at the 24 FAonth Frequency, 'Nhich is baseei on the refueling cycle. Therefore, the Frequency Ylt'as concludeei to be acceptable froFA a reliability staneipoint.
REFERENCES 1. 10 CFR 50, Appendix A, GDC 41.
- 2. UFSAR, Section 6.5.3.
- 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-lnformcd Modification to Selected Required End States for BWR Plants, December 2002.
GRAND GULF B 3.6-101 u:mcR 1so12 Page 129 of 197
Drywell B 3.6.5.1 BASES SURVEILLANCE SR 3.6.5.1.1 (continued) REQUIREMENTS the The normal Surveillance Frequency is Hill ooour suoh that the dryHell bypass leakage limit Hill controlled under the be mrneeded, If during the performance of this required Surveillance Surveillance the drywell bypass leakage rate is greater Frequency Control than the drywell bypass leakage limit the Surveillance Program. Frequency is increased to every 48 months. If during the performance of the subsequent consecutive Surveillance the drywell bypass leakage rate is less than or equal to the drywell bypass leakage may be
,im~it-,-t-h-e~F-re~q-u_e_n_c_y--,resumed. If during the rformance of two consecutive f Surveillances the drywell bypass leakage is greater than speciied in the the drywell bypass leakage limit the Surveillance Frequency Surveillance ce every 24 months. The 24 Frequency Control months Frequency is maintained until during the performance Program of two consecutive surveillances the drywell bypass leakage .__~"'-~~~~~~~....,rate is less than or equal to the drywell bypass leakage limit, at which time the 10 year Frequency may be resumed.
For two Surveillances to be considered co ecutive the Surveillances must be performed at least 1 months apart. (Ref. 3). specified in the Surveillance SR 3.6.5.1.2 Frequency Control Program The exposed accessible drywell interior and exterior surfaces are inspected to ensure there are no apparent physical defects that would prevent the drywell from performing its intended function. This SR ensures that drywell structural integrity is maintained. The'Frequency was chosen so that the interior and exterior surfaces of the drywetl can be inspected in conjunction with the inspections of the primary containment required by 10 CFR 50, Appendix J (Ref. 2). Due to the passive nature of the drywell structure, the specified Frequency is sufficient to identify (continued) GRAND GULF B 3.6-105 LBDCR 1§817 Page 130 of 197
Drywell B 3.6.5.1
. BASES SURVEILLANCE SR 3.6.5.1.2 (continued)
REQUIREMENTS
*component degradation that may affect drywell structural integrity.
- SR 3 . 6. 5 . 1. 3 This SR requires ,a test to be performed to verify air lock leakage of the drywell air lock at pressures z 3 psid. ~
24 month Froquonoy is based on tho need to porfortfl this aurvoillanoo ~ndor tho oonditions that apply during a plant outage and tho potential for violating tho dr~1oll boundary. This Surveillance verifies that the drywell air lock leakage rate supports meeting the drywell bypass leakage lim.it (SR The Surveillance 3.6.5.1.1). For performance monitoring purposes the test Frequency is administrative limit on drywell air lock leakage is~ 2 controlled under the scfh. Operating mxporionoo has shmm those oompononts Surveillance usually pass tho auruoillanoo and requires tho aR to be porfortflod onoo oaoh refueling oyolo. Therefore, tho Frequency Control Froquonoy Has oonoludod to be aoooptablo frotfl a reliability Program. standpoint. REFERENCES 1. UFSAR, Chapter 6 and Chapter 15.
- 2. 10 CFR 50, Appendix J.
- 4. GNRI-96/00162, Issuance of Amendment No. 126 to Facility Operating License No. NPF Grand Gulf Nuclear Station, Unit 1 (TAC No. M94176), dated August 1, \1996.
GRAND GULF B 3.6-IOSa R..e.isieH ?Je. 2 Page 131 of 197
Drywell Air Lock B 3.6.5.2 BASES ACTIONS D.1 and D.2 (continued) based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.5.2.1 REQUIREMENTS The air lock door interlock is designed to prevent simultaneous opening of both doors in the air lock. Since-both the inner and outer doors of the air lock are designed to withstand the maximum expected post accident drywell pressure, closure of either door will support drywell OPERABILITY. Thus, the door interlock feature supports drywell OfERABILITY while the air lock is being used for personnel transit in and out of the drywell. Periodic The Surveillance testing of this interlock demonstrates that the interlock Frequency is will function as designed and that simultaneous inner and controlled under-the outer door opening will not inadvertently occur. Quo to Surveillance Frequency Control is opened, this test is only required to be porforffiod onoo Program. ouory 24 :months. Tho 24 ffionth Froquonoy is bdsod on tho nee~ to perform. this Survoillanoo under tho roduQod roaotiuity oonditions that apply during a plant outage and tho potential for violating ~ho dr~roll boundary. Operating oxporionoo has shmm those oo:mpononts usually pass tho Suruoillanoo Hhon performed and tho Frequonoy is based on tho refueling oyolo. Therefore, the Frequonoy Has conoludod to be aoooptable froffi a reliability standpoint. The Surveillance is modified by a Note requiring the Surveillance to be performed only upon entry into the drywell. (continued) GRAND GULF B 3.6-lfl R:e. isiea ~:ie. 2 Page 132 of 197
Drywell Isolation Valve(s) B 3.6.5.3 BASES SURVEILLANCE SR 3.6.5.3.1 REQUIREMENTS This SR ensures that the 20 inch drywell purge isolation valves are closed as required or, if open, open for an a~lowable reason. This SR is intended to be used for drywell purge isolation valves that are fully qualified to close under accident conditions; therefore~ these valves are allowed to be open for limited periods of time. This SR has been modified by a Note indicating the SR is not required to be met when the drywell purge supply or exhaust valves are open for pressure control, ALARA or air quality considerations for personnel entry, or Surveillances or
'special testing of the purge system (e.g., testing of the containment and drywell ventilation radiation monitors)
The Surveillance that require the valves to be open provided that, in MODES Frequency is 1 and 2 the.20 inch and 6 inch containment vent and purge controlled under the system supply and exhaust lines are isolated. Tho Jl day Surveillance Frequency Control Program. SR 3.6.5.3~2 This SR requires verification that each drywell isolation manual valve and blind flange that is r~quired to be closed during accident *conditions-is closed. The SR helps to 1 ensure that drywell bypass leakage is maintained to a minimum. Due to the location of these devices, the Frequency specified as "prior to entering MODE 2 or 3 from MODE 4, if not performed in the previous 92 days," is
,appropriate because of the inaccessibility of the devices and because these devices are operated under administrative controls and the probability of their misalignment is low.
Two Notes are added to this SR. The first'Note allows valves and blind flanges located in high radiation areas to J?e verified by use of administrative controls.. Allowing verification by administrative controls is considered acceptable since access to these areas is typically restricted during MODES 1, 2, and 3. Tµerefore, the prob 0 bility of misalignment of these devices, once they have been verified to be in their proper position, is low. A second Note is included to clarify that the drywell isolation valves that a-re open under administrative controls are not required to meet the SR during the time that the devices are open. (continued) GRAND GULF B 3.6-118 Re. isieH }Je. 9 Page 133 of 197
DRYWELL ISOLATION VALVE(S) B 3.6.5.3 BASES SURVEILLANCE SR 3.6.5.3.3 REQUIREMENTS (continued) Verifying that the isolation time of each power operated, automatic drywell isolation valve is within limits is required to demonstrate OPERABILITY. The,isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analysis. The isolation time and Frequency of this SR are in accordance with the INSERVICE TESTING PROGRAM. SR 3.6.5.3.4 Verifying that each automatic drywell isolation valve closes on a drywell isolation signal is required to prevent bypass leakage frbm the drywell following a OBA. This SR ensures each automatic drywell isolation valve will actuate'to its The Surveillance isolation position on a drywell isolation signal. The LOGIC Frequency is SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.7 overlaps this SR to controlled under the provide complete testing of the safety function. ~ 24 month Frequency is based on the need to perform this Surveillance eurueillance under the conditions that apply during a plant Frequency Control outage and the potential for an unplanned transient if the Program. eurveillance Here perform.ad Hith the reactor at pm10r, sinoe isolation of penetrations ;rnuld eliminate oooling uater floH and disrupt the normal operation of many oritioal oomponent'.s. Operating mrperienoe has shoun these oom.ponents usually pass this eurueillanoe uhen perform.ad at the 24 mdnth Frequenoy. Therefore, the Frequenoy Has oonoluded to be aooeptable from a reliability standpoint.
\
REFERENCES 1. UFSAR, Section 6.2.4.
- 2. GNRI-96/00162, Issuance of Amendment No. 126 to Facility Operating License No. NPF Grand Gulf Nuclear Station, Unit 1 (TAC No. M94176), dated August 1, 1996.
GRAND GULF B 3.6-119 LBDCR 1S91Q Page 134 of 197
Drywell Pressure B 3.6.5.4 BASES (continued) SURVEILLANCE SR 3.6.5.4.1 REQUIREMENTS This SR provides assurance that the limitations on drywell-The Surveillance to-primary containment differential pressure stated in the Frequency is LCO are met. The 12 ho1:1r Freq1:1enoy of this ~g uas controlled under the developed, based on operaling eKperienoe related to Surveillance trending of dryirnll pressure uariations during thp Frequency Control applioable MODJii::~ and to assessing pronimity to the spooified LCO differential pressure limits F1:1rthormore, Program. the 12 ho1:1r Froq:Henoy is oonsiderod adeqt1ato ih uieH of other indioations available in the oontrol room, ,inol1:1ding alarms, to alert the operator to an abnormal dr~rell. presst1ro oondition. REFERENCES 1. UFSAR, Section 6.2.1.
- 2. UFSAR, Section 3.8.
- 3. UFSAR, Section 6.2.1.1.6.
- 4. UFSAR, Section 6.2.7.
GRAND GULF B 3.6-122 R:e.isiett ~Je. 9 Page 135 of 197
Drywell Air Temperature B 3.6.5.5 BASES SURVEILLANCE SR 3.6.5.5~1 (continued) REQUIREMENTS The drywell average air temperature is the arithmetical average of the temperatures at the following locations: Elevation Azimuth
- a. -119'-0" 20°S A s 70°
- b. .=119'-0" 110°s A s 160° .
- c. =119'-0" 200°s A s 250°
- d. =119'-0" 290°s A s 340°
* =139 I -0 11 20°S A s 70 ° -
- f. =139'-0" 110°s A s 160°
- g. =139'-0" 200°s A s 250°
- h. =139'-0" 290°s A s 340°
- i. =166'-0" 20°S A s 70°
- j. =166'-0" 110°s A s 160°
- k. -166'-0" 200°s A s 250° The Surveillance 1.
1
-1 66 I -0" 290°s A s 340° Frequency is controlled under the The 24 hour Frequenoy of the ~g uas deueloped based on Surveillance operating mcperienoe related to uariations in dryuell average air temperature uariations during the applioable Frequency Control D40DJ;;::~ Furthermore, tho 24 hour Frequenoy is mmsidered Program. adeq~ate in uiou of other indioations a:uailable in the control room, inol~ding alarms, to alert the operator to an abnormal dryuell air temperature condition.
REFERENCES 1. UFSAR, Section q.2. GRAND GULF B 3.6-125 Re. isieH ~Je. 1 Page 136 of 197
Drywell Vacuum Relief System B 3.6.5.6 BASES SURVEILLANCE SR 3.6.5.6.1 REQUIREMENTS Each vacuum breaker and its associated isolation valve is verified to be closed (except when being tested in accordance with SR 3.6.5.6.2 and SR 3.6.5.6.3 or when the vacuum breakers or isolation valves are performing their intended design function) to ensure that this potential The Surveillance large bypass leakage path is not present. )This Surveillance is performed Frequency is by observing the vacuum breaker or associated isolation valve position controlled under the indication. The 7 day i;Feq1:1eRoy is based on engineOFing j1:1dgFRent, is Surveillance Frequency Control . isolation valve stat1:1s available to the J3lant J3eFsonnel, and has been Program. sho,.vn to be aeeeJ3table thF01:1gh opemting mEpeFienoe. Two Notes are added to this SR. The first Note allows drywell, vacuum: breakers or isolation valves opened in conjunction with the performance of a Surveillance to not be considered as failing this SR. These periods are controlled by plant procedures and do not represent inoperable drywell vacuum breakers or isolation valves. A second Note is included. to clarify that vacuum breakers or isolation valves open due to an actual differential pressure, are not considered as failing this SR. SR 3.6.5.6.2 Each vacuum breaker and its associated isolation valve must be cycled to ensure that it a.pens adequately to perform its design function and returns to the fully closed position. The Surveillance This Surveillance includes a CHANNEL FUNCTIONAL TEST of the Frequency is isolation valve differential pressure actuation instrumentation. This controlled under the provides assurance that the safety analysis assumptions are valid. +Re Surveillance Frnq1:1eRoy of this S1:1FVeillanoe is in aoooFdanee \ivith lnsen,<ioe Test Frequency Control PFOQFOFR. Program. ' (continued) GRAND GULF B 3.6-130 LBDCR 1q943 Page 137 of 197
Drywell Vacuum Relief System
. B 3.6.5.6 BASES SURVEILLANCE '
REQUIREMENTS SR 3.6.5.6.3
-+--
Verification of the opening pressure differential is necessary to ensure that the safety ,analysis assumption that the vacuum breaker or isolation valve will open fully at a differential pressure of 1.0 psid is valid. This SR verifies that the pressure differential required to open the vacuum-breakers is~ 1.0 psid and that the isolation valve differential pressure actuation instrumentation*opens the valve at 0.0 to 1.0 psid for the drywell purge vacuum relief subsystem and -1.0 to 0.0 psid for the post-LOCA vacuum relief subsystems (drywe II minus containment). This SR includes a CHANNEL CALIBRATION of I The Surveillance the isolation valve differential pressure actuation instrumentation. This Frequency ls Surveillance includes a calibration of the position indication as necessary. controlled under the The 24 month Freq~eney is baseel on the noeel to periorm this Surveillance Frequency *Control potqntial for 'liolating the elryv,ell eoun,elary. Opemting e*porienee has Program. shown these eomponents usually pass the Sl::lrveillanep when J3erforn=ieel at the 24 month Frequeney, *whieh is easeel *on the refueling eyele. Therefore, the Frequency \Vas eonelueloel to tao aeee19table from a reliaeility ptanelpoint. REFERENCES. 1. 2. UFSAR, Section 6.2. NEDC-32988-A, Revision 2, Technical Justification to Support Ris~ Informed Modification to Selected Required End States for BWR Plants, December 2002. t GRAND GULF B3.6-131 LBDCR 14943 Page 138 of 197
SSW System and U HS B 3.7.1 BASES ACTIONS (continued) If any both SSW subsystems are inoperable, or more than one of the UHS cooling towers have inoperable cooling tower fan(s), the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 12 hours and in MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.1.1 REQUIREMENTS The Surveillance This SR ensures adequate long term (30 days) cooling can be Frequency is maintained. With the UHS water source below the minimum level, the controlled under the UHS basin must be declared inoperable. The 24 hour Frequency is based Surveillance ( Frequency Control Program. SR 3.7.1.2 . Operating each cooling tower fan for ~ 15 minutes ensures that alrfans The Surveillance a!e OPERABLE and that all associated controls are functioning properly. Frequency is It also ensures that fan or motor failure, or excessive vibration can be controlled under the detected for corrective action. The 31 day Frequency is based on Surveillance operating meperienee, the lmovm reliability of the fan units, the Frequency Control redunetaney a*,<ailable, and the low 13robability of signifieant def!Jradation of Program. the cooling trnuer fans ooeurring bekveen Surveillanees. SR 3.7.1.3 Verifying the correct alignment for each required manual, power operated, and automatic valve in each SSW subsystem flow path provides assurance that the proper flow paths will exist for SSW operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve is also allowed to be in the nonaccident position and yet considered in the correct position, provided it can be automatically realigned to its accident position within the required time. This SR does not require any testing or valve manipulation; rather, it involves verification that those,valves capable of potentially being mispositioned are in the correct position. (continued) GRAND GULF .8 3.7-6 L~DCR 1404e Page 139 of 197
SSW System and U HS B 3.7.1 BASES SURVEILLANCE SR 3.7.1.3 (continued) REQUIREMENTS This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. Isolation of the SSW System to components or systems does not necessarily affect the OPERABILITY of the SSW subsystem. As such, . when all SSW pumps, valves, and piping are OPERABLE, but a branch The Surveillance connection off the main header is isolated, the SSW subsystem needs to Frequency is be evaluated to determine if it is still OPERABLE. controlled under the Surveillance The 21 day FFequeney is based on engineCFing judgn:mnt, is consistent Frequency Control 'c.\'ith the prncedural controls goveming valve operation, a,nd ensums Program. eoFFect valve positions. SR3.7.1.4 This SR verifies that the automatic isolation valves qf the SSW System will automatically switch to the safety or .emergency position to provide cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated initiation signal. This SR also verifies the automatic start capability of the SSW pump and cooling tower fans in each subsystem. The LOGIC The Surveillance SYSTEM FUNCTIONAL TEST in SR 3.3.5.1.6 overlaps this SR to provide Frequency is complete testing of the safety function. controlled under the Surveillance OpeFating e*perienoe has shovm that these coFF1ponents usually pass the Frequency Control SR \'..'hen perforFfled on the 24 ffionth p'requenoy. Therefore, this Program. p'requenoy is ooneluded to be aoeeptable iroFfl a reliability stanetJ3oint. REFERENCES 1. Regulatory Guide 1.27, Revision 2, January 1976.
- 2. UFSAR, Section 9.2.1.
- 3. UFSAR, Table 9.2-3.
'\
- 4. UFSAR, Section 6.2.1.1.3.3.
- 5. UFSAR, Chapter 15.
- 6. UFSAR, Section 6.2.2.3.
- 7. UFSAR, Table 6.2-2.
- 8. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR i
Plants, December 2002. GRAND GULF B 3.7-7 LBDCR 14043 Page 140 pf 197
HPCS SWS B 3.7.2 BASES
- SURVEILLANCE SR 3.7.2.1 (continued)
REQUIREMENTS those valves capable of potentially being mispositioned are in the correct
- position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.
Isolation of the HPCS SWS to components or systems may*render those components or systems inoperable, but may not affect the OPERABILITY of the HPCS SWS. As such, when all HPCS SWS pumps, valves,*and piping are OPERABLE, but a .branch connection off the main header is The Surveillance isolated, the HPCS SWS needs to be evaluated to determine if it is still Frequency is OPERABLE. controlled under the Surveillance The a1 day FFequeney is based on engineeFing judgment, is consistent Frequency Control Vlith the pmeeduml eontmls gmmming *,alve opemtion, and ensuFes Program .. ooFFeet valve positions. SR 3.7.2.2 This SR verifies that the automatic isolation valves of the HPCS SWS will automatically switch to the safety or emergency position to provide cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated initiation signal. This SR also verifies the automatic start capability of the HPCS SWS pump. The LOGIC SYSTEM FUNCTIONAL TEST in The Surveillance SR 3.3.5.1.6 overlaps this SR to provide complete testing of the safety Frequency is function. controlled under the Surveillance Frequency Control SR '..-:hen pertoFmed at the 24 month Fmqueney. Themfom, Program. thisFmqucney is eoneluded to ,be aeeeJ3table fmm a mliability standpoint. REFERENCES 1. UFSAR, Section 9.2.1.
- 2. UFSAR, Chapter 6.
- 3. U FSAR, Chapter 15.
GRAND GULF B 3.7-10 LBDGR 13943 Page 141 of 197
CRFA System B 3.7.3 BASES (continued) SURVEILLANCE SR 3.7.3.1 REQUIREMENTS This SR verifies that a subsystem in a standby mode starts from the control room on demand and continues to operate. Standby systems should be checked periodically to ensure that they start and function properly. As the environmental and normal operating eonditions of this system are not se'lere, testing eaeh subsystem onee e'lery month pro'lides an adequate eheel<: on this system. Operation for~ 15 The Surveillance continuous minutes demonstrates OPERABILITY of the system. Periodic Frequency is operation ensures that blockages fan or motor failure, or excessive controlled under the vibration can be detected for corrective action. Furthermore, the a1 day Surveillance Frequency Control Program. SR 3.7.3.2 This SR verifies that the required CRFA testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The VFTP includes testing HEPA filter performance, and minimum system flow rate. Specific test frequencies and additional information are discussed in detail in the VFTP. SR 3.7.3.3 This SR verifies that each CRFA subsystem starts and operates and that the isolation valves close in s 4 seconds on an actual or simulated The Surveillance initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR Frequency is 3.3. 7 .1.1 overlaps this SR to provic;ie complete testing of the safety controlled under the function. '.!Vhile this Surveillanee ean be performed v:ith the roaster at Surveillance power, 013erating mc13erienee has sho~vn these eoFA13onents usually 19ass Frequency Control the Surveillanee \.\'hen 13ertormed at the 24 month rrequeney, v:hieh is Program. based on the refueling eyele. Therefore, the rrequeney 'NOS eoneluded to be aeee13table from a reliability standpoint. SR 3.7.3.4 This SR verifies the OPERABILITY of the CRE boundary by testing for unfiltered air inleakage past the CRE boundary and into the CRE. The details of the testing are specified in the Control Room Envelope Habitability Program. (continued) GRAND GULF B 3.7-16b LBDCR 14Q4Q Page 142 of 197
Control Room AC. System B 3.7.4 BASES ACTIONS E.1 (continued) During OPDRVs if the Required Action and associated Completion Time . of Condition B is not met, action must be taken to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the control room. This places the unit in a conditipn that minimizes risk. If applicable, actions must be initiated immediately to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Actions must continue until the OPDRVs are suspended. SURVEILLANCE SR 3.7.4.1 REQUIREMENTS The Surveillance, This SR verifies that the heat removal capability of the system is sufficient Frequency is coi:,trolled to remove the control room heat load assumed in the safety analysis. un_,der the Surveillance . The SR. consists of a combination of testing and calculation. The 24 Frequency Control Program*. REFERENCES 1. FSAR, Section 6.4. i
- 2. FSAR, Section 9.4.1.
I
- 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
GRAND GULF B 3.7-21 LBDCR 14Q4a Page 143 of 197
Main Condenser Offgas B 3.7.5 BASES ACTIONS 8.1. and 8.2 (continued) inoperable systems and components, consideration of the result&, determination of the acceptability of entering MODE 3, and establishment of risk management actions, if appropriate. LCO 3.0.4 is not applicable to, and the Note does not preclude, changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. The allowed Completion Time is reasonable, based on operating , experience; to reach the required unit conditions from full power conditions in an orderly manner an~ without challenging unit systems. SURVEILLANCE SR 3.7.5.1 and 3.7.5.2 REQUIREMENTS SR 3.7.5.2, on a 21 day Frequeney,Tequires an isotopic analysis of an offgas sample to ensure that the required limits a.re satisfied. The noble gases to be sampled include Xe-133, Xe-135, Xe-138, Kr-85, Kr-87, and Kr-88. If the measured rate of radioactivity increases significantly (by
~ 50% after correcting for expected increases due to changes in THERMAL POWER), an isotopic analysis is also performed within The SR 3.7.5.2 4 hours after the increase is noted as required by SR 3. 7 .5.1, to ensure Frequency is that the increase is not indicative of a sustained increase in the controlled under the radioactivity rate. The a1 day rre<:1uency is adequate in vieVv' of other Surveillance instn:m:ientation that continuously n:ionitor the o~as, and is aeeeJ3tal31e Frequency Control eased on OJ3eratin~ mEJ3erienee.
Program. SR 3.7.5.2 is modified by a Note indicating that the SR is not required to be performed until 31 days after any SJAE is in operation. Only in this condition can radioactive fission gases be in the Main Condenser Offgas System at. significant rates. REFERENCES 1. FSAR, Section 15.7.1.
- 2. NUREG-0800.
- 3. 10 CFR 100.
- 4. NEDC-32988-A, Revision 2, Technical Justification to Support Risk- ~
Informed Modification to Selected Required End States for BWR Plants, December 2002. - GRAND GULF B 3.7-24 LBDGR 14043 Page 144 of 197
Fuel Pool Water Level B 3.7.6 BASES (continued) LCO The specified water level preserves the assumption of the fuel handling accident analysis (Ref. 2. As such, it is the minimum required for fuel ~ movement within the spent fuel storage pool and upper containment fuel storage pool. APPLICABILITY This LCO applies whenever movement of irradiated fuel assemblies occurs in the associated fuel storage racks since .the potential for a release of fission products exists. ACTIONS Required Action A.1 is modified by a Note indicating that LCO 3.0.3 does not apply. If moving irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not a sufficient reason to require a reactor shutdown. When the initial conditions for an accident cannot be met, steps should be taken to preclude the accident from occurring. With either fuel pool level less than required, the movement of irradiated fuel assemblies in the associated storage pool is suspended immediately. Suspension of this activity shall not preclude completion of movement of an irradiated fuel assembly to a safe position. This effectively precludes a spent fuel handling accident from occurring. SURVEILLANCE SR 3.7.6.1 REQUIREMENTS This SR verifies that sufficient water is available in the event of a fuel The Surveillance handling accident. The water level in the, spent fuel storage pool and Frequency. is upper containment fuel storage pool must be checked periodically. +Re controlled under the 7 day Frequency is aeeet3table, eased on ot3erating mEf3erienee, Surveillance eonsidering that the v.mter voluffle in the t3ool is norfflally staele and water Frequency Control level ehanges are eontrolled by unit f3Foeedures. Program. (continued) GRAND GULF B 3.7-26 LDC 990ea Page 145 of 197
Main Turbine Bypass System B 3.7.7 BASES (continued) B.1 If the Main Turbine Bypass System cannot be restored to OPERABLE status or the LHGR and MCPR limits for(two or ~ore inoperable Main Turbine Bypass valves are not applied, THERMAL 'POWER must be reduced to< 70% RTP. As discussed in the Applicability section, operation at <70% RTP results in sufficient margi~ to the required limits, and the Main Turbine Bypass system is not required to protect fuel integrity during the feedwater controller failure, maximum demand event. The 4 hour Completion Time is reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.7.1 The Surveillance Cycling each Main Turbine Bypass valve through one complete Frequency is cycle of full travel demonstrates that the valves are controlled under the echanically OPERABLE and will function when required.~ Surveillance Frequency Control Program. SR 3.7.7.2 The Main Turbine Bypass System is required to actuate The Surveillance automatically to perform its design function. This SR Frequency is demonstrates that, with the required system initiation controlled under the valves will. actuate to their required position.
. (
Surveillance Frequency Control outa~o and booauso of tho potential for an unplanned Program. transient if tho guruoillanoo uoro performed Hith tho roaotor at pmrnr. REFERENCES None GRAND GULF B 3.7-30 LBE>CR 14@34 P~ge 146 of 197
AC Sources - Operating
- 8 3.8.1 1
BASES. SURVEILLANCE SR 3.8.1.1 REQUIREMENTS (continued) This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power. The breaker alignment verifies that each breaker is The Surveillance in its correct position to ensure that distribution buses and loads are Frequency is connected to their preferred power source and that appropriate controlled under the independence of offsite circuits is maintained. The 7 day Frequency is Surveillance Frequency Control Program. SR 3.8.1.2 and SR 3.8.1.21 -f-These SRs help to ensure the availability of the standby electrical power "- su.pply to mitigate DBAs and transients and maintain the unit in a safe shutdown condition. To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs have been modified by Notes (the Note for SR 3.8.1.21 and Note 2 for SR 3.8.1.2) to indicate that all DG starts for these Surveillances may be preceded by an engine prelube period and
+
followed by a warmup period prior to loading. For the purposes of this testing, the DGs are started from standby conditions. Standby conditions for a DG mean that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations for DG 11 and DG 12. For DG 13, standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the -system by natural 1 circulation. In order to reduce stress and wear on diesel engines, the manufacturer recommends that the DGs be gradually accelerated to synchronous speed prior to loading. These modified start procedures are the intent of Note 3 of SR 3.8.1.2, which is only applicable when such procedures are used. (continued) GRAND GULF B 3.8-15 LBDCR 1404a Page 147 of 197
AC Sources - Operating B 3.8.1 BASES ' SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.21 {continued). REQUIREMENTS (continued)
, SR 3.8.1.21 requires that, at a~184 elay frequenoy, the DG starts from standby conditions and achieves required voltage and frequency within 10 seconds. The DG's ability to maintain the required voltage and frequency is tested by those SRs which require DG loading. The 10 second start requirement supports the assumptions in the design basis LOCA analysis (Ref. 5). The start requirements may not be applicable to 3.8.1.2 (see Note 3 of SR 3.8.1.2), when a modified start procedure as described above is used. If a modified start is not used, the start requirements of SR 3.8.1.21 apply. Since SR 3.8.1.21 does require a 10 second start for each DG, it is more restrictive than SR 3.8.1.2, and it may be performed in lieu of SR 3.8.1.2.* This is the intent of Note 1 of SR 3.8.1.2. Similarly, the performance of SR 3.8.1.12 or SR 3.8.12.19 also satisfies the requirements of SR 3.8.1.2 and SR 3.8.1.21. In addition to 1' the SR requirements, the time for the DG to reach steady state operation is periodically monitored (data is taken once per 6 months during the performance of SR 3.8.1.21) an.d the trend evaluated to identify degradation of governor and voltage regulator performance.
i The DGs are started for this test by using one of the following signals: manual, simulated loss of offsite power by itself, simulated loss of offsite The Surveillance power in conjunction with an ESF actuation test signal, or ar-i ESF Frequencies are actuation test signal by itself. 1 controlled under the Surveillance
*t Frequency Control guidelines for assessfftent of ~Hosoi generator t3erforfftanoe (Ref. 14).
Program. The 184 day frequency for SR a.8.1.21 is a reeluction in colel testing seAsisteRt witA CeAeris Letter 84 1e ~Ref. 7). TAese i:creei1,1eAsies JlF9'1iele adequate assurance of DG OPERABILITY, 'Nhile Fflinimizing elegradation . resulting from testing. SR 3.8.1.3 This Surveillance demonstrates that the DGs are capable of synchronizing and accepting great~r than or equal to the equivalent of the maximum expected accident loads. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source. {continued) GRAND GULF B 3.8-15a LBDGR 14043 Page 148 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.3 (continued)
,REQUIREMENTS Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between 0.9 lagging and 1.0.
The 0.9 value is conservative with respect to the design rating of the machine, while 1.0 is an operational limitation to ensure circulating currents are minimized. The load band for DG 11 and 12 is provided to avoid routine overloading of the TOI DG. Routine overloading may result The Surveillance in more frequent teardown inspections in accordance with vendor Frequency is recommendations in order to maintain DG OPERABILITY. controlled under the Su~eillance Frequency Control Program. Note 1 modifies this Surveillance to indicate that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized. Note 2 modifies this Surveillance by stating that momentary transients because of changing bus loads do not invalidate this test. Note 3 indicates that this Surveillance shall be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations. Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.
- i SR 3.8.1.4 This SR provides verification that the level (expressed as an equivalent volume in gallons) of fuel oil in the day tank is at or above the level which ensures adequate fuel oil for a minimum of 30 minutes of DG operation at the maximum expected* post LOCA load:
(continued) GRAND GULF B 3.8-16 LDC 02024 Page 149 of 197_'
AC Sources - Operating 8 3.8.1 BASES SURVEILLANCE SR 3.8.1.4 (continued) REQUIREMENTS The Surveillance Frequency is operatoFS would be muare of any large uses of fuel oil during this period. controlled under the Surveillance Frequency Control SR 3.8.1.5 Periodic removal Program.
' Microbiological fouling is a major cause of fu I oil degradation. There are numerous bacteria that can grow in fuel oil a cause fouling, but all must a
have water environment in order to survive. Removal of water from the fuel oil day tanks onoe every a1 days eliminates the necessary environment 'for bacterial survival. This is an effective means of controlling microbiolo*gical fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, The Surveillance contaminated fuel oil, and breakdown of the fuel oil by bacteria. Frequent Frequency is checking for and removal of accumulated water minimizes fouling and controlled under the provid_es data regarding ~he wat~rtight integrity of the fu~I- oil system. =l=Ae Surveillance Frequency Control 49t:-This SR is for preventive maintenance. The presence of water does Program. not necessarily represent a failure of this SR provided that accumulated water is removed during performance of this Surveillance. SR 3.8.1.6 This Surveillance demonstrates that each required fuel oil transfer pump operates and 'transfers fuel 011 from its associated storage tank to its associated day tank. It is required to support the continuous operation of standby power sources. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERA,BLE. (continued) GRAND GULF 8 3.8-17 Revision ~Jo. 0 Page 150 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.6 (continued) REQUIREMENTS The design of the fuel transfer systems is such that pumps operate automatically in order to maintain an adequate volume of fuel oil in the The Surveillance day tanks during or following DG testing. Therefore, a 31 day P:requeney Frequency is ) is speeifieei to eorrespond to the mm~iA::iuFFt interval f.or DG testing. controlled under the Surveillance Frequency Control SR 3.8.1.7 Program. Under accident conditions, loads are sequentially connected to the bus by the load sequencing panel. The seqµencing logic controls the permissive and starting signals to motor breakers to prevent overloading of the bus power supplies due to high motor starting currents. The load sequencing ( ensures that sufficient time exists for the bus power supply to restore frequency and voltage prior to applying the next load and that.safety analysis assumptions regarding ESF equipment time delays are not violated. Reference 2 provides a summary of the automatic loading of ESF buses. This Surveillance is a manual test of the load shedding and sequencing panels and verifies the load sheddi,ng and sequencing panels respond within design criteria to the following test inputs: LOCA, bus The Surveillance undervoltage, bus undervoltage followed by LOCA, and LOCA followed Frequency is . by bus undervoltage. controlled under the Surveillance The P:requeney of 31 elays is based on engineering jueJgFRent, tal<:ing into Frequency Control consideration plant eonditions requires to perforffi the Surveillanee. Program. OpeFating mEperienee has shown that these eoA::iponents usually pass the SR *1.vhen perforA::ied at the 31 day P:requeney. Therefore, the P:requeney was concluded to be acceptable froffi a reliability standpoint. SR 3.8.1.8 . The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. (continued)
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GRAND GULF B 3.8-18 LBDGR 1ao43 Page 151 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.8 (continued) REQUIREMENTS inteneled to be eonsistent *..vith mcpeetea fuel eyele lengths. 0130Fating e*perienee has shown that thpse eomponents usually pass the SR 'Nhen performeel on the 24 month Frequeney. Therefore, the Frequeney was '1' eonelueleel to ee aeee~table ffOFfl a reliability stanefraoint. {continued) GRAND GULF B 3.8-18a LBDGR 1ao42 Page 152 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR ,3.8.1.9 (continued) REQUIREMENTS )
- 2) tripping its associated single largest load with the DG solely supplying the bus. J If this load were to trip, it would result in the loss of the DG. As required by IEEE-308 (Ref. 13), the load rejection test is acceptable if the increase in diesel speed does not exceed 75% of the difference between
- synchronous speed and the overspeed trip setpoint, or 15% above The Surveillance synchronous speed, whichever'is lower. For the Grand Gulf Nuclear Frequency is, Station the lower value results from the first criteria.
controlled under the, Surveillance The 24 month l=FOE1Ueney is eonsistent with the Fesommeneation of Frequency Control Regulator=y Guiao 1.9 (Ref. a). Program. Testing performed for this SR is normally conducted with theDG being tested (and the associated safety-related distribution subsystem) connected to one offsite source, while the remaining saf~ty-related systems are aligned to another offsite source. This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations. This SR has been modified by two Notes. Note 1 states; Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
- 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required\ performance is available; and
- 2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintafn OPERABILITY or, reliability.
Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of S-0.9 for DG 11 and DG 13 and s 0.89 for DG 12. These power factors are representative of the actual inductive loading the DGs would see under design (continued) GRAND GULF B 3.8-20 Page 153 of 197
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AC Sources - Operating - B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 (continued) REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Testing performed for this SR is normally conducted with the DG being Frequency Control tested (and the associated. safety-related distribution subsystem) Program. connected to one offsite source, while the remaining safety-related systems are aligned to another offsite source. This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations. This SR has been modified by a two Notes. Note 1 states that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
- 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
- 2) Post maintenance testing that requires performance of this Surveillance iri order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain 'OPERABILITY ,
or reliability. Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of s 0.9 for DG 11 and DG 13 ands 0.89 for DG 12. These power factors are representative of the actual inductive loading the DGs would see under desigq basis accident conditions. Under certain conditions, however, Note 2 allows the surveillance to be conducted at a power factor above the limit. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to within the
- limits results in voltages on the emergency busses that are too high.
Under these conditions, the power factor should be maintained as close as practicable to the limit while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage (continued) GRAND GULF B 3.8-22 LBDGR 1d042 Page 154 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.11 (conUnued) REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Testing performed for this SR is normally conducted with the DG being* Program. tested (and the associated safety-related distribution subsystem) connected to one offsite source, while the remaining safety-related systems are aligned to another offsite source. This minimizes the possibility of common cause failures resulting from offsite/grid voltage . perturbations. This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. For the purpose of this testing,
- the DGs must be started from standby conditions, that is, with the engine /
coolant and oil being continuously circulated and temperature maintained consistent with manufacturer recommendations for DG 11 and DG 12. For DG 13, standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the *system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates througti the system by natural circulation. Note 2 is not applicable to DG 13. The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge plant safety systems. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
- 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
,2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, I provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
(continued) GRAND GULF B 3.8-23 LBDGR 1a042 Page 155 of 197
AC Sources - Operating B 3.8.,1 BASES SURVEILLANCE SR 3.8.1.12 REQUIREMENTS (continued) This Surveillance demonstrates that the DG automatically starts and achieves the required voltage and frequency within the specified time (10 seconds) from the design basis actuation signal (LOCA signal) and operates for~ 5 minutes. The 5 minute period provides sufficient time to demonstrate stability. SR 3.'8.1.12.d ensures that emergency loads are energized from the offsite electrical power system on an ECCS signal without loss of offsite power. The requirement to verify the connection and power supply of permanent and auto-connected loads is intended to satisfactorily show the relationship of these loads to the loading logic for loading onto offsite power. In certain circumstances, many of these loads cannot ~ctually be connected or loaded without undue hardship or potential for undesired operation. For instance, ECCS injection valves are not desired to be stroked open, high pressure injection sys,tems are not capable of being operated at full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of operation. In lieu of actual demonstration of the connection and loading of these loads, testing that adequately shows the capability of the offsite power system to perform these functions is acceptable. This testing may include The Surveillance any series of sequential, overlapping, or total steps so that the entire Frequency is connection and loading sequence is verified. controlled under the Surveillance Frequency Control required to perform the Surveillanee and is intended to be eonsistent *11ith Program. the mEpeoted fuel eyele lengths. Operating mEperienoe has shown that these eomponents l:JSually 13ass tt:ie SR *..vhen performed at the 24 month , \ Frequeney. Theref.ore, the Frequenoy 'NOS oonoluded to ee aooet3taele from a reliaeility standpoint. , I Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related distribution subsystem) connected to one offsite source, while the remaining safety-related
, , systems are aligned to another offsite source. This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations.
(continued) GRAND GULF B 3.8-24 Page 156 of 197
AC Sources - Operating
, B 3.8.1 BASES SURVEILLANCE SR 3.8.1.13 (continued)
REQUIREMENTS The Surveillance minor problems that are not immediately detrimental to emergency Frequency is operation of the DG. controlled under the Surveillance Tl=te 24 month Freql:leney is eased on engineering juelgment, tal<ing into 0 Frequency Control consideration plant eonditions required to perform the Surveillanee, and is Program. intended to be eonsistont with oxpeetea ft:.tel eyelo lengths. Operating mEperioneo has shov:n that those components usually pass tho SR when performed at the 24 A=lonth Frequoney. Tt:mrefore, the FreEfueney was eoneluded to be aeeeptablo from a reliability standpoint. Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related distribution subsystem) connected to one offsito source, while tho remaining safety-related systems are aligned to another offsito source. This minimizes tho possibility of common cause failures resulting from offsite/grid voltage perturbations. {continued) GRAND GULF B 3.8-25a L8DCR 13Q4a Page 157 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.13 (continued) REQUIREMENTS The SR is modified by a Note. Credit may be taken for unplanned events
'that satisfy this SR. Examples of unplanned events may include:
- 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
- 2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
SR 3.8.1.14 Regulatory Guide 1.9 (Ref. 3) requires demonstration onee per 24 months 'i-that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours - 22 hours of which is at a load equivalent to the continuous rating of the DG, and 2 hours of which is at a load equivalent to 110% of the continuous duty rating of the qG. An exception to the loading requirements is made for DG 11 and DG 12. DG 11 and DG 12 are operated for 24 hours .at a load greater than or equal to the maximum expected post accident load. Load carrying capability testing of the Transamerica Delaval Inc. (TOI) diesel generators (DG 11 and DG 12) has been limited to a load less than that which corresponds to 185 psig brake mean effective pressure (BMEP). Therefore, full load testing is performed at a load~ 5450 kW but< 5740 kW (Ref. 15). The DG starts for this Surveillance can be performed either from standby or hot conditions. The provisions for prelube and warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR. In order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing must be performed using a power factor (continued) GRAND GULF B 3.8-26 L~DCR 14Qs4 Page 158 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued) REQUIREMENTS s 0.9. This power factor is chosen to be-representative of the actual design basis inductive loading that the DG could experience. During the test the generator voltage and frequency is 4160 +/- 416 volts and ~ 58.8 Hz and s 63 Hz within 10 seconds after the start signal and the steady The Surveillance state generator voltage and frequency is maintained within 4160 +/- 416 Frequency is volts and 60 +/- 1.2 Hz for the duration of the test. controlled under the Surveillance Frequency Control Regulatory Guide 1.Q (Ref. 2) takes into eonsideration plant eonditions Program. Fe'='uiFea to peFfoFm the Surveillanee; anci is intenaed to be eonsistent with mEpeeted fuel eyele lengths. This Surveillance is modified by three Notes. Note 1 states that momentary transients due to changing bus loads do not invalidate this test. The DG 11 and 12 load band is provided to avoid routine overloading of the TOI DG. Routine overloading may result in more , frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY. Similarly, momentary power factor transients above the limit do not invalidate the test. Note 2 stipulates that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
- 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
- 2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE,
. provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
Note 3 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of s 0.9 for DG 11 and DG 13 ands 0.89 for DG 12. These power factors are representative of (continued) GRAND GULF B 3.8-27 LBDGR 12042 Page 159 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.15 (continued)
-REQUIREMENTS and frequency within 10 seconds. The 10 second time is derived from the The Surveillance requirements of the accident analysis to respond to a design_ basis large Frequency is break LOCA.
controlled under the Surveillance The 24 month Freql::leney is consistent *.uith the recommendations of '} Frequency Control Regl::llatory Guide 1.9 (Ref. a). Program. This SR has been modified by two Notes. Note 1 ensures that the test is performed with the diesel sufficiently hot. The requirement that the diesel has operated for at least 1 hour at full load conditions or until operating temperatures stabilized prior to performance of this Surveillance is based on manufacturer recommendations for achieving hot, conditions. The DG 11 and 12 load band is provided to avoid routine overloading of the TOI pG. Routine overloads may* result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY. Momentary transients due to changing bus loads do not invalidate this test. Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing. SR 3.8.1.16 As required by Regulatory Guide 1.9 (Ref. 3) this Surveillance ensures that the manual synchronization and load transfer from the DG to each required offsite source can be made and that the DG can be returned to ready-to-load status when offsite power is restored. It also ensures that the undervoltage logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs. The DG is considered to be in ready-to-load status when the DG is at rated speed and voltage, the output breaker is. The Surveillance op~n and can receive an* auto-close signal on bus undervoltage, and the Frequency is load sequence logic is reset. controlled- under the I Surveillance The Freq1:.mncy of 24 months is consistent with the recoFAR=lenaations of --,- Frequency Control Regulatory Guide 1.9 (Ref. a) and talms into consideration plant Program. eonetitions requireet to perform the Surveillanee. Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related (continued) GRAND GULF B 3.8-28 L8DGR 1~Q4~ Page 160 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.17 (continued) REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Testing performed for this SR is normally conducted with the DG being Program. tested (and the associated safety-related distribution subsystem) connected to one offsite source, while the remaining safety-related systems are aligned to another offsite source. This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations. Credit may be taken .for unplanned events that satisfy this SR. Examples of unplanned events may include:
- 1) Unexpected op*erational events which cause the equipment toI perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
- 2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required* to maintain OPERABILITY or reliability.
- SR 3.8.1.18 Under accident conditions, loads are sequentially connected to the bus by the load sequencing panel. The sequencing logic controls the permissive and starting signals to motor breakers to prevent overloading of the bus power supplies due to high motor starting currents. The 10% load sequence time interval tolerance ensures that sufficient time exist)s for the bus power supplies to restore frequency and voltage prior to applying the next load and that safety analysis assumptions regarding ESF equipment time delays are not violated. Reference 2 provides a summary of the automatic loading of ESF buses.
\ (continued) GRAND GULF B 3.8-30 LBDGR 1ag4a Page 161 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.18 (continued) REQUIREMENTS The Surveillance Frequency is
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controlled under the Surveillance Frequency Control Program. {continued) GRAND GULF B 3.8-30a LBDGR 1e04a Page 162 of 197
AC Sources - Operating
. B 3.8.1 BASES SURVEILLANCE SR 3.8.1.18 (continued)
REQUIREMENTS
. This SR is modified by a Note. The reason for the Note is that performing the Surveillance during these MODES would challenge plant safety systems. Credit may be taken for unplanned events that satisfy this SR.
Examples of unplanned events may include:
- 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
- 2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction "'(ith maintenance required to maintain OPERABILITY or reliability:
SR 3.8.1.19 I In the event of a OBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to ESF systems so that the fuel, RCS, (and containment design limits are not exceeded. This Surveillance demonstrates the DG operation, as discussed in the Bases for SR 3.8.1.11, during a loss of offsite power actuation test signal in conjunction- with an ECCS initiation signal. For the purposes of this Surveillance the DG 13 autoconnected emergency loads are verified to be energized in s 20 seconds. In lieu of actual demonstration of connection and l9adihg of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable. The Surveillance This testing may include any series of sequential, overlapping, or total Frequency is steps so that the.entire connection and loading sequence is verified. controlled under the 1 ' .
- Surveill~mce The Froe;1:1eney of 24 FRonths tal~es into eonsieieration plant eonelitions i Frequency Control
- req1:1ireei to perforffl the Swveillanee and is intended to be eonsistont with Program .. an mcp,eeteei f1:1el eyele lengtt=I of 24 fflontl=ls. "L Testing performed for this SR is normally conducted with the DG being tested (and the associated safety...related (continued}
GRAND GULF B 3.8-31 LBDGR 1d04d Page 163 of 197
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.20 (continued) REQUIREMENTS This surveillance is performed when the unit is shut down ana its 10 year Freq~eney is eonsistent 'Nith the reeofflfflenaations of Regl::llatory Gl::liae The Surveillance Frequency is controlled under the This SR is modified by a Note. The reason for the Note is to minimize Surveillance wear on the DG during testing. For the purpose of this testing, the DGs Frequency Control must be started from standby conditions, that is, with the engine coolant Program. and oil continuously circulated and temperature maintained consistent with manufacturer recommendations for DG 11 and DG 12. For DG 13, standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural circulation. I . SR 3-.8.1.21 (See SR 3.8.1.2) (continued) GRAND GULF B 3.8-33 LSDGR 09010 Page 164 of 197
AC Sources - Operating B 3.8.1 BASES (continued) REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.
- 2. UFSAR, Chapter 8.
- 3. Regulatory Guide 1.9, Revision 3.
- 4. UFSAR, Chapter 6.
- 5. UFSAR, Chapter 15.
- 6. Regulatory Guide 1.93.
- 7. Generic Letter 84-15, July 2, 1984.
- 8. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
- 9. 10 CFR 50, Appendix A, GDC 18.
Regulatory Guide 1.1a7. ANSI C84.1, 1982. ASME, Boiler and Pressure Vessel Code, Section XI. Not used. IEEE Standard 308.
~JUMARG 87 00, Revision 1, August 1991.
- 15. Le,tter from E.G. Adensam to L.F. Dale, dated July 1984.
- 16. GNRl-96/00151, Amendment 124 to the Operating License.
- 17. Generic Letter 94-01, May 31, 1994.
- 18. GNRl-98/00016, Amendment 134 to the Operating License.
- 19. GNRl-2000/00065, Grand Gulf Nuclear Station, Unif1 - Issuance of Amendment Re: Generic Changes to Improved Standard Technical Specifications, Amendment 142 to the Operating License.
- 20. ER-GG-2002-0466, Evaluation of P75 Standby Diesel Generators to Regulatory Guide 1.9, Rev. 3.
GRAND GU,LF B 3.8-34 LBDGR 1404a Page 165 of 197
Diesel ftie.l* Oil, JllPC? :Oil, ~:r,~ :$tarllp.g. fir s 3 ..s.) ACJI*ONS {c ;*r, tJnµ ~ d) With a Required; Action .an:d ias:s:octated Cbmp}ettqn Time not .. rnet, or the: .stored- diesel frJ~fl oi 1, lube o{l or .starting ai.r S:u.r,*sYst~rri rto,t wfthih Jiinits fqr rdc)son*s dther trrari addres{ed* by Cpn_<.lfti:q_ns A thr9ugh D~ fhe _a~s:Octatgd OG rn.aY pe *. . .... i ncap*able:of *pe*rtormi ng its irytende:d- *funci:i on ,and must b'~ irnrnediateIY <le*ctared_ ; noperahl e_~_ SURVEfLLA.NGE SR L8.3 .. l
.RfQUlREM ENTS Jhfs_.
capacftY SR provide_s veri*fi,caJion that thfr.e inventory* ()f fuel o;-1 in th.e s:torag.e tan.ks to supp9rt ~ach OG's operation for .T days at ils su-rveillante :fe:sttng
;;s: *ah _a*qeq.u,at.e as_*pte'~c.rTbed_ bj Technic'a) Spec'ifi¢:aJiorfs (5l4P KW fop Qivisi'ori. i and 2,. 33QO KW f()r Div'-is:f'on 3:r~ *. Tl}is*
i.*_ capaci ty_.:exceeos. the *m;~Xi mlerm expe*cted:. PQS:t LOG/\ lo;aqi ng. The 7 day peri oa is Sl.tff.i ci ent- t+me to *pl ace:. the' Lin ft in a The Surveillance saf¢ s:hutdowry: c"dnditiHn. and lo b ri .rjg: tr( replen}$hfoEfrit fqeJ Frequency is fro111 an qff:s ile locafi'on ~ .* ** * * * *** * * * * * * ** *
- controlled under the Surveillance The_*11- d3 0, Ere-qnehcy iside'1'1ath to iabstife fb'at a sotfi'de'tit Frequency Control s jr pp)ji_ -.6 f f i'i eJ a i] -is ii miJJ abl es ~fr ce J,jq Je keJ alatro s ,a 6e Program. P'N!l.i QQii, J_liil9_ ,,~, t 9_fi'-l~iilt~P.E' n@11l~ :~ .. iPJilr2 # ~-~y l?F'.39 rrsQt
'of ht'tl 6i'l ~~li'i'fi§: t~Hl ~@Pi.a~L This. s~rvefllarjC$ ~n*sqres th'al sufficient_]Ube_'.di:l irivehto'r'.y.
is: ijyaflatiJe t-c>: isllppor,t; at least- f '.ctc1ys. p.f .ma)<Jmum ~xpg.cJ:ei post LOCA 1 oad ope*rati on fot each DG. This: reqt.d-remen,t, is based- On th:e* OG -rhanufa;'<+/-turer' s t6hsu'mptioh Values for. the run fi Tl1e ()f -the :o,L* I111p l ldi tn thi s $R lhe hlqtd'rement rs tp verjfy :bite capqti'fH ty *to. transfer the lu.be p.i l (t~qm * {_ts
- storage lt>cati.On* 'to the: DG when the DG lube :oil *sump idoes nfrt, hold a:dequa,te f nv'ento.rj f9r 7 d'fi}s' df: rna_ximum, ex'p*~cJe:d The Surveillance pqstJO.Ci\ 1o*ad opE?fati on wjt.hq_ut: the level. r-~µc:htng th:~: .
Frequency is manufacturer's recomm_ended mini mum leve 1 . controlled under the Surveillance A $1 day Frhqu.c;i,c;yi is _acleqµat¢ tbq'rt$:~re t!=taf ;a .stfHtc.i efit Frequency Control Juae :e*i l s:upply. ts: OflS:i te, ~-ifl.EC .D>(i~ start.s aicief l",U~ timp~* .~fe Program. elestJY ff!er,ffeeeel ey Ure i;laAt. sta.H. {tofrtinued)
*GRAND GUlJ B 3*.*8.,.46 LOG 99052 Page 166 of 197
Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.3 (continued) REQUIREMENTS limits, would not have an immediate effect on bG operation. This Surveillance ensures the availability of high quality fuel oil for the DGs. Fuel oil degradation during long term storage shows up as an increase in insolubles, mostly due to oxidation. The presence of insolubles does not mean that the fuel oil will not burn properly in a diesel engine. However, the insolubles can cause fouling of filters and fuel oil injection equipment,
'-'Yhich can cause engine failure.
The Frequency of these Surveillances on the stored fuel oil takes into consideration fuel oil degradation trends indicating that overall fuel oil quality is unlikely to change between Frequency intervals. SR 3.8.3.4 This Surveillance ensures that, without the aid of the refill compressor, sufficient air start capacity for each DG is available. For DG 11 and DG 12 the starting air system is required to have a minimum capacity for one emergency DG start attempt above the air pressure interlock, and multiple manual start attempts below the interlock, without recharging the air start receivers. For DG 13 the starting air system is required to have a minimum capacity for five successive DG start attempts without recharging-the air start receivers. The pressure specified in this SR reflects the value The Surveillance at which this can be accomplished, but is not so high as to result in failing Frequency is the limit due to normal cycling of the recharge compressor. controlled under the Surveillance -~Tl1e 31 elay Fre!!uenoy takes inte aseeunt U1e eaJ!aeity, eaJ!aBility, Frequency Control "redundancy, and diversity of the /\G sources and other indications Program. a*,ailaele in the oontrol rooA=t, ineluelin§ alarA=ts, to alert the 013erator to belmu norA=tal air start 13ressure. This Surveillance Requirement is met for a given division when one of the two starting air trains for the respective diesel generator meets the 1' pressure specified in the Surveillance Requirement. (continued) GRAND GULF B 3.8-48 LBOCR 1eQ1e Page 167 of 197
Diesel Fuel Oil, Lube Qi 1 , ano *sJ,~rting Afr B '3.8.3. BASES SURVEILLANCE. SR 3.H.3~5. Periodic removal REQUi RtMENTS (cont i nuec;f). Mlcrob.i o log1eal. foulfog is a. major* caus_e o degradation. There are numerous batteri a that can .grow in fLteJ oil an~ cause fouling, but all mus hav.E: a w*ater envi ronm~n.t. in .order to survi_ve. *. ' ' ' o:f water -fro.m the storage tanks, 01,ce. evqPy 92 d:ays el imtr:iates. th~e** necessary
~nvfronm~nt for bact~ffal ~Of~i~al. tht~ i~ th~ ~dst effective mea Ii s of controlling *mi crobi ologic a.l foul i n:g _. ln addition, it eliminate.s the potential for wat~r e_n'_trainment in the fu~l oil during DG ope.ration. Water may come from any. 6f s*eve*ral sources, i ntludi ng condensation*:, ground w.ater; rain w~ter, contaminated fuel oil, and *-rrorh breakdown>
The Surveillance of the fue.l oil by bcicteri a. Frequ~nt checking* for* and . Frequency is removal
- o:f .accumulated water minimizes fou 1Jng ,and p r.oyi des controlled under the data regarding the watertight i ntegritY bf the Jliel oil Surveillance s)'stem. Hi.e StH=vei 11 aFttC FrequeAcic;s a*re es*fabl i'sJ,eEI. by Regulator:); Gui cfo L 137 ( Ref'. 2) ..
- This SR is. lqr pr~Ventive Frequency Control maint~nance_., The presence .of wat.er sloes n.ot nece.ssarily Program. represent a '.failure of *this SR pro\/ided that ac'turrfulated
.water is rerno.ved dur.ing performance of the Surveill,?nce.
RE,FERENCES L. UFSAR, Sittion 9.5.4.
- 2. Re'gul atory Gui de 1.137.
- a. ANSI Nl95, Appe~dix B, 1976.
Cconti nued)
.GRAND GQ L.F *s 3}8.~49 LDCfJ9050 Page 168 of 197 *
'\
DC Sources - Operating
~ B 3.8.4 BASES (continued)
ACTIONS With the Division 3 DC electrical power.subsystem inoperable for reasons other than its associated battery charger inoperable, the HPCS System may be incapable of performing its intended functions and must be immediately declared inoperable. This declaration also requires entry into applicable Conditions and Required Actions of LCO 3.5.1, ."ECCS - Operating." F.1 and F.2 *'l If the Division 3 DC electrical power subsystem cannot be restored to '\ OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, . based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. The Completion Time to bring the unit to MODE 4 is consistent with the time required in Regulatory Guide 1.93 (Ref. 1 7). SURVEILLANCE SR 3.8.4.1 REQUIREMENTS Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the charging system and the ability of the batteries to perform their intended function. Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery (or battery cell) and maintain the battery (or The Surveillance battery cell) in a fully charged state. The voltage requirements are based Frequency is on the nominal design voltage of the battery and are consistent with the controlled under the initial voltages assumed in th~ battery sizing calculations. The 7 day Surveillance FFeE1l:leney is eensistent with ITl8Al:lffletl:IFeF's Feeem!Tlendatiens ana Frequency Control IEeE 4ep (Ref. 9). Program. SR 3.8.4.2 Visual inspection to detect corrosion of the battery cells and connections, or measurement of the resistance *of each inter-cell, inter-rack, inter-tier, and terminal connection, provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance. (continued) GRAND GULF B 3.8-56 LBDC~ 1404a Page 169 of 197
DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.2 (continued) REQUIREMENTS The Surveillance Frequency is ' controlled under the days. This Frequency is considered aeeeptablo based on operating Surveillance m~raerienee related to detesting corrosion trends. Frequency Control Program. SR 3.8.4.3 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance. The presence of physical damage or deterioration does not necessarily represent a failure of this SR, provided an evaluation determines that the physical damage or The Surveillance deterioration does not affect the OPERABILITY of the battery (its ability to Frequency is
- perform its design function).
controlled under the Surveillance The Surveillance Frequency of 24 months is consistent 'Nith the Frequency Control recommendations of Regulatory Guide 1.22 (Ref. 10) and Regulatory Program. Guide 1.129 (Ref. 11), *..vhieh state that the battery service test should bp perforR=teeJ during refueling operations or at some other outage, with intervals_ betv,een tests not to e*eeed 24 mqnths. Operating e*perienee has shown that these components usually pass the SR 'Nhen performed at the 24 month Frequency. Therefore,*the Frequency was eoneluded to be aeeeptable from a reliability standpoint (continued) GRAND GULF B 3.8-56a LBDGR 1404~ Page 170 of 197
DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.4 and SR 3.8.4.5 REQUIREMENTS (continued) Visual inspection and resistance measurements of inter-cell, inter-rack, inter-tier, and terminal connections provides an indication of physical damage or abnormal deterioration that could indicate degraded battery condition. The anti-corrosion material is used to ensure good electrical connections and to reduce terminal deterioration. The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection. The removal of visible corrosion is a preventive maintenance SR. The presence of visible corrosion does not necessarily represent a failure of this SR, provided visible corrosion is removed during performance of this The Surveillance Surveillance. For the purposes of this SR oxidation is not considered Frequencies are corrosion provided the resistance of the connection(s) is within limits. controlled under the Surveillance Frequency Control juelgment, tal<:ing into consieleration the elesireel unit conelitions to J3eriorm Program. the Surveillance. 013erating mcJ3erienoe has shown that these c9mJ3onents usually pass the SR *when J3erformed at the 24 month ~ Frequeney. Therefore, the Frequeney '..",ms concludeel to be aoceJ3table from a reliability stanelJ3oint. SR. 3.8.4.6 Battery charger capability requirements are based on the design capacity
~
1 of the chargers (Ref. 4). According to Regulatory Guide 1.32 (Ref. 10), 1 the battery charger supply is required to be based on the largest / ' combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to the fully charged state, irrespective of the status of the unit during these The Surveillance demand occurrences. The minimum required amperes and duration Frequency is ensure that these requirements can be satisfied. controlled under the Surveillance The Surveill,anoe Frequency is acceJ3table, given the unit oonelitions Frequency Control requireel to periorm the test and tt=te other aelfflinistrative controls mcisting Program. to ensure adequate charger 13eriormance eluring these 24 month intervals. In adelition, this Fref.1ueney is intended to be consistent 'Nith exJ3eeteel fuel cycle lengths. (continued) GRAND GULF B 3.8-57 LBDGR 1404d Page 171 of 197
DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 REQUIREMENTS (continued) A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length (4 hours for Division 1 The Surveillance and Division 2 and 2 hours for Division 3) correspond to the design duty Frequency is cycle requirements as specified in Reference 4. controlled under the Surveillance ~TRe Sl,lFVeillaR!Je i;'reEJl,leRey ef 24 FAeRtRs is eeRsisteRt witR tRe Frequency Control reooFAFAendations of Regulatory Guide 1.d2 (Ref. 10) anel Regulatory Program. Guide 1.129 (Ref. 10), 'IJhieh state that the battery serviee test should be perforFAed during refueling operations or at soFAe other outage, 'Nith intervals bew,een tests not to e>ceeed 24 FAonths. This SR is modified by two Notes. Note 1 allows the once per 60 months performance of SR 3.8.4.8 in lieu of SR 3.8.4.7. This substitution is acceptable because SR 3.8.4.8 represents a more severe test of battery capacity than SR 3.8.4.7. The reason for Note 2 is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. The Division 3 test may be performed in MODE 1, 2, or 3 in conjunction with HPCS system outages. Credit may be taken for unplanned events that satisfy the Surveillance. SR 3.8.4.8 A battery performance test is a test of constant current capacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test: The test is intended to determine overall battery degradation due to age and usage. The acceptance criteria for this Surveillance is consistent with IEEE-450 (Ref: 9) and IEEE-485 (Ref. 12). These references recommend that the 'f... battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements. (continued) GRAND GULF B 3.8-58 LBDGR 14042 Page 172 of 197
_) DC Sources - Operating 8 3.8.4 BASES SURVEILLANCE SR 3.8.4.8 (continued) REQUIREMENTS
~e4-j-HPdce+HaRf~m.f=eeHf;~IJ4f.:~~~-t:-fS.-Re~~-eY-R=M~~ lfthe The normal attery shows degradation, or if the battery has reached 85% of its Surveillance expected life and capacity is < 100% of the manufacturer's rating, the
~requency is Surveillance Frequency is reduced to 12 months. However, if the battery controlled under the shows no degradation but has reached 85% of its expected life, the Surveillance Surveillance Frequency is only reduced to 24 months for batteries that Frequency Control retain capacity ~ 100% of the manufacturer's rating. Degradation is Program. indicated when the battery capacity drops by more than 10% of rated capacity relative to its capacity on the previous performance test or is below 90% ofthe manufacturer's rating. These Frequencies are based on
. the recommendations in IEEE-450 (Ref. 9).
This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge
*safety.systems. The Division 3 test may be performed in MODE 1, 2, or 3 in conjunction with HPCS system outages. Credit may be taken for unplanned events that satisfy the Surveillance.
REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.
- 2. Regulatory Guide 1.6, March 10, 1971.
- 3. IEEE Standard 308, 1978.
- 4. UFSAR, Section 8.3.2.
- 5. UFSAR, Chapter 6.
- 6. UFSAR, Chapter 15.
- 7. Regulatory Guide 1.93, December 1974.
- 8. NEDC-32988-A, Revision 2, Technical Justification to Support Risk}
Informed Modification to Selected Required End States for BWR Plants, December 2002. l
- 9. IEEE Standard 450, 1987. vi~
- 10. Regulatory Guide 1.a2, February 1977.
- 11. Regulatory Guide 1.129, December 1974 .
. 12. IEEE Standard 485.
GRAND GULF 8 3.8-59 LBDCR 14Q4~ Page 173 of 197
Battery Cell Parameters 8 3.8.6 BASES I ACTIONS A.1, A.2, and A.3 (continued) Continued operation is only permitted for 31 days before battery cell parameters must be restored to within Category A and B limits. Taking into consideration that while battery capacity is degraded, sufficient capacity exists to perform the intended function and to allow time to fully restore the battery cell parameters to normal limits, this time is acceptable for operation prior to declaring the DC batteries inoperable.
- When any battery parameter is outside the Category C limit for any connected cell, sufficient capaciW to supply the maximum expected load requirement is not assured and the corresponding DC electrical power subsystem must be declared inoperable. Additionally, other potentially extreme conditions, such as not completing the Required Actions of Condition A within the -required Completion Time or average electrolyte temperature of representative cells falling below 60°F, also are cause for immediately declaring the associated DC electrical power subsystem inoperable.
SURVEILLANCE SR 3.8.6.1 REQUIREMENTS The Surveillance The SR verifies that Category A battery cell parameters are consistent with IEEE-450 (Ref. 3), which recommends regular battery inspections Frequency is including float voltage, specific gravity, and electrolyte level of pilot cells. controlled under the
) The 7 aay t=requeney ensures that these ins13eetions are t3efl0rfflea 'Nithin Surveillance that l=requeney reGOfflfflenaea by IEEE 4a0 (Ref. d~.
Frequency Control Program. SR 3.8.6.2 The Surveillance The quarterly inspection of ~pecific gravity and voltage is consistent with Frequency is IEEE-450 (Ref. 3). In addition, within 72 hours of a battery overcharge > controlled under the ust be demonstrated to meet Category B limits. This Surveillance inspection is also-consistent with IEEE-450 (Ref. 3), which recommends Frequency Control special inspections following a severe discharge or overcharge, to en:5ure Program. that no significant degradation of the battery occurs as a consequence of such overcharge. (continued) _) GRAND GULF 8 3.8-67 Revision No. 1 Page 174 of 197
- sµ*RvtI.r5LAN*c.E *SFf 'j {8i6.3'
'~-~QU:t,~E~~NJ:~
. *to.ontiJN~tDi Jhts;. :s*µrve.'ffiance verttJ~.a.tion inc1t . _1t11e *.~v~r~§.¢\ F'~,rµp¢fa{µr~
*q:*( .r~p:r~sen~*?ttye' w~n;~ ('.eyerj.' 'si~'th ¢'onrj~pt~~' *ce}Tt 'Js;... ' . T
~>6Qt)f }$*._*co_n~sl~tent*'.With. _*a *:r-~c*a~~¢I1da.{ii9.n: .<tf* te:E;g,~A:?:P*_. . . ..
n~~~~e~t~~~v!f~;~:5 t~k.~ur~~~~e:l!£~f~~~}a;6~6~~:~~~~~&~~.t~* tower *than po~m.al' lemp~ta}ures, ::a*c~ ,to .jnh\blto:r te,~~c:e b'a\~ery c.apa*¢.ity:. ' Thtsi. $R ensures j:h~t th~:?)P~t~tip:g*
*t.~.11ltl'er,~tµre$ rematn* *~J.thtn* an: ~c;c:e,ptable.' .?Pef.~t:tn:9.'r~ftg~.
.. *1 Jniit.~ 'fSi ba*sed: .rin,*.manufat.furef'.-*S
*This'.:
*reccjmtnendatton's~
1 The Surveillance Frequency is controlled under the Surveillance th:i:.s'.*iabl.:e_ :~~Jine,aJe$ the_ Ti.mit}. :Mi. :el~~'.:~:rillvf~ leV¢)\ **f.lo.a¥: Frequency Control :voltage" ~and spe.i:.i.fic: :,grav:i.ty -f..o..r* :three'. ,d(ifjfe:ren.£.* ca.1:~egot-fes. Th~ ,mean{ng of 'each ,category :;:s'. d',:s'cUs*s.ecL Program. oelow~* ** ** **
'..C:~t~g*~r.y: :A '.d$,fi*~f.fij,e* fip.rlilaJ
- <Je:s.ignate*q *pJlc,t celJ ltt. ea.ch. bat;~r.t/
tPa.ramft~tJ,i~f,. 'fpr ~~'¢,fi . .* . .
- J~.~ <:¢ell:$;' s.~il~~c:*iea:
- il1itr6h~il:i1iir!~,i~;!~i~\1JftM~ti~~,~i;*rtit:;iil~~
"(he ¢a:t~g9ry A. 'linrfts, spetJffea:: fQr*,ii:ect1;Q.lyieF]:e.v.~l clte; 1
- b:a.$~dJ>n *-marilt f act~rer-~*J: .~reco~~n~~tipt)S'. ,a1'\cl,;aY;"~:}.CO~Sii sten t-..
)1izthth;e -~uid~nce: :,nIEEE,r,450. fR~f~ 3)'.t\ .,W:itfr)the.. ~x'tta . *. :
*1,M . iri9h a1 lowanc~_.aboye: ttle .h.i;gij wat~r l~yf!l: fndi¢~l}:o'r1 ;for*
<>,P¢.rating m~r,gin t9_ ac~ou.nt. :fo(:ten1p¢t:cJ.tU\7f t~J1Cf;.pijirg~* .
effe~~,$:-:: .*. :Irt:~ddtti_~.fl it.9Jtl1Js _ '_ .~1lo!{~f.l~*~,j 'f9qtrj9{$) ~! t<?*' TabT~}-Bt~>r p:ermi.~:s: Jhe_ :eJ~~lrqJyte:_. l~~ijl. /t'if ~'t ~.MY~; oth~; 11:ti~~!l~~ii !ifiir:9?~~ii!1?W!t1!i1iM:riii~iti:#lif:~ 1:p,ari~J~t. ,c;~p,abiJ1JY. {~<)na.i ntai n~d in th.~>:*ey.e_njt :o;f: :t.t:~n~tent
*iconcfi:t:i:Pll$,. JEE,.E:~4-~Q: :(:R(:!f~- 3*Y recommgnds*_Jhap: _:g:l,ectr:pl¥te***
1'..~.Wfl .reaq:i;ng~ >S:00.UlQ, '.be,* mc1de onJy (~fter,<the; battery .fias
,been :at. floc1t.: charge :fpr at least:. 72 hours*..
- the*;<e?tegory 'A.1Jmtt*. . speclfied :fpr 'f:J~c1't,'V0:]:6:~g~* if c!:,:2*~1l. V*:p~r ce)J .* ,. /Tbi<s;'.. vctl.u~: .ls: _ij~s~~*}~D- *:i~Jf . . *.. * *. *
- ~.~CQrnrilendatto.~ oJ J:;EE-4~.o /(:.R~f:~:. }J,, *.wli.i!t:h\ s:;al~fs 'Ap~:t
- p:_r9 l 6J19.e~ opetttlpr('of' ¢~1 }s; below :t~J~ -V:.t:'af! t~9Qci :Jh~
liJf ~~pe:~~~t\<ly gf :~tJl$.. * ** * * * * * * * * * * * * -*
....... : Jc;c)_~t~*~nue.dL Page 175 of 197
Distribution Systems - Operating 8 3.8.7 BASES ACTIONS D.1
* (continued)
- With the Division 3 electrical power distribution system inoperable, the rnvision 3 powered systems are not capable of performing their intended functions. Immediately declaring the high pressure core spray inoperable allows the ACTIONS of LCO 3.5.1, "ECCS - Operating," to apply appropriate limitations on continued reactor operation.
Condition E corresponds to a level of degradation in the electrical distribution system that causes a required safety function to be lost. When more than one Condition is entered, and this results in the loss of a required function, the plant is in a condition outside the accident analysis. Therefore, no additional time is justified for continued operation. LCO 3.0.3 must be entered immediately to commence a controlled shutdown. SURVEILLANCE SR 3.8.7.1 REQUIREMENTS Meeting this Surveillance verifies that the AC and DC electrical power distribution systems are functioning properly, with the correct circuit breaker alignment. The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus. The Surveillance The verification of proper voltage availability on the buses ensures that Frequency is the required voltage is readily available for motive as well as control controlled under the functions for critical system loads connected to these buses. The 7 day Surveillance FFequenoy tal'ies into account the Fedundant capability of the AC and DC Frequency Control eleetFical pov,eF elistribution subsystems, and otheF indications availaele in Program. the co~trnl room that alert the operatoF to suesystem malfunctions. REFERENCES 1. UFSAR, Chapter 6.
. 2. UFSAR, Chapter 15.
- 3. Regulatory Guide 1.93, December 1974.
- 4. UFSAR, Section 8.3.
- 5. NEDC-32988-A, Revision 2, Technical Justification to Support Risk- '1_.
Informed Modification to Selected Required End States for BWR I' Plants, December 2002. GRAND GULF 8 3.8-78 LBDGR 1<1Q<1~ Page 176' of 197
Distribution Systems - Shutdown B 3.8.8 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, A.2.4, and A.2.5 (continued) would not be entered. Therefore, Required Action A.2.5 is provided to direct declaring RHR-SDC inoperable, which results in taking the appropriate RHR-SDC ACTIONS. The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the plant safety systems may be without power. SURVEILLANCE SR 3.8.8.1 REQUIREMENTS f This Surveillance verifies that the required AC and DC electrical power distribution sub~ystems are functioning properly, with the buses energized. The verification of proper voltage availability on the required The Surveillance buses ensures that the required power is readily available for motive as Frequency is well as control functions for critical system loads connected to these controlled under the buses. The 7 day Frequency tal~es into aeeount the redundant eapabilit:y Surveillance of the eleetrieal pmuer distribution subsystems, a& \.VOii as other
- Frequency Control indieations available in the eontrol room that alert the operator to Prograry,. subsystem malfunotions.
REFERENCES 1. UFSAR, Chapter 6.
- 2. UFSAR, Chapter 15.
GRAND GULF B 3.8-83 , Revision No. 1 Page 177 of 197
Refueling Equipment Interlocks B 3.9.1 BASES ACTIONS A.l, A.2.1,
?
and A.2.2 (continued) control rods to be withdrawn in accordance with LCO 3.10.6 while complying with th~se actions. This verification that all required control rods are fully inserted is in addition to the periodic verifications required by SR 3.9.3.1 and SR 3.10.6.2. Like Required Action A.1, Required Actions A.2.1 and A.2.2 ensure that unacceptable operations are blocked (e.g., loading fuel into a cell with the control rod withdrawn.) The alternative option (Required Actions A.2.1 and A.2.2) also allows fuel movement to continue rather'than halting refueling act,vities to perform SR 3.9.1.1 should it become due before completion of fuel movement activities. This option should not be used to eliminate the first performance of the SR before starting in~vessel fuel movements. The objective of the option is to provide flexibility under limited circumstances, not to disable the refueling interlocks indefinitely and is only allowed for a period not to exceed 31 days, after which time performance of the SR 3.9.1.1 would be required. SURVEILLANCE SR 3.9.1.1 REQUIREMENTS Performance of a CHANNEL FUNCTIONAL TEST demonstrates each required refueling equipment interlock will function properly when a simulated or actual signal indicative of a required condition is injected into the logic. The CHANNEL FUNCTIONAL TEST may be performed by any series of The Surveillance sequential, overlapping, or total channel steps so that the Frequency is entire channel is tested. controlled under the Surveillance ,The 7 day Frequency is ~ased on engineering judgment and is Frequency Control considered adequate i~ vie~, of other indications of refueling interlocks and their associated input status th~t Prqgram. are availa~le to unit operations personnel. Should this SR become due before completion of fuel movement activities, fuel movement may continue rather than halting refueling activities to perform the SR provided thar Required Actions A.2.1 and A.2.2 are met. As discussed above, this opt,i on should not be used to (continued) GRAND GULF B 3.9-4 LDC 03020 Page 178 of 197
Refuel Position One-Rod-Out Interlock B 3.9.2 BASES (continued) SURVEILLANCE SR 3.9.2.1 REQUIREMENTS Proper functioning of the refuel pos1t1on one-rod-out interlock requires the reactor mode switch to be in refuel. During control rod withdrawal in MODE 5, improper positioning of the reactor mode switch could, in some instances, allow improper bypassing of required interlocks. Therefore, this Surveillance imposes an additional level of assurance that the refuel position one-rod-out interlock wi 11 be OPERABLE when required. By "l ocl'osition B 3.9 .. 3 BASES
.APPLICABLE Control *tod posJtiC>n s*atisfies: Crtterion .3 of the :N-RC Poli~y
.* SAFE!Y . ANALYSES *:sfateme*nt * *
. {cpntJnued) .
LCO All con~r61 _fdds. must b~ fully .ihs:erted durtn~f 'pplic~ble tefu~l i_ng conditfons to mirdrniz~ the. pr9bability (jf 'arr inadvert~nt criticality durlrig refu~ling.
.APPLICABILITY During MODE 5:, loading* fuel *tnto :~ore c.elts wfth:* cC>ntrQl
.rods, wtthdrawn may result in inadvertent cc:rlti ca}ity.
Therefore, the cont.rol ro~s must he. inserted before loadJng fuel into a core cell. All control rods must be. inserted before loading. ftiel to ensur~ that a fuel, 1Qaclfn~ :error does. not r¢sull
'rod withdrawn~
in load in~ f'u,e 1 into. a co.re .cell .with' 'the control ln MOPES 1, 2, 3; ~nd 4,. the reactor press9.t~: ve~seJ .head is ()0, ar\d no'fue.l 'l~c1dtflg ;actiYHte$ -~re JjOS$JbJe-; .. Therefore, this- Spectfic.at;fon i$ n<>t _appli~able in thes,e MODES~ AC.TIO~$ With all c::ontrol .rnds Mt fully inse.rt~~ duffn_g t.he applicable condJtidns, an inadvertE?n( crit}'qHfty .G9Uld
-0(:CUr that *i S: not analyz~d in the UFSAR.' Al r :fuel _ lpad:ing operations must be. immecliately suspended ... $uspensfon *of .*
- these activities sha l1 not preclude comp let:ion of movement of a. component to a safe posi+/-idn~
SlJRVElLLANcE. SR 3.9.3;1 REQUlHE.M~NTS
*ourtryg refµ~l trig,,* to: ensure that the. r~a~t'<lt re~aii,s' The Surveillance .subcrittcal, *al 1. control_ r9d:s ;mu.sf b~ fully *tn5>~rfed_ prior Frequency is t~l. .an:d *_ :dud Q9 *JueJ *, o~dtng *..* ..PeY'Jo.dJc. 'c:fie~k.s of the* control rod position ensure thts cOn~itton i.s mafntainEHL controlled under the Surveillance ~The. 12 he.Hr Fre~tte11ey lattes .i flte eefl.s h.iet=ati efl: the . . .
Frequency Control preeeclttral earrtrels 61l ~()flltral re:d ffl6)'efileflt ~lff}fl~ refuel iflg Program. . tls well as the reatou:la11t r1:1;,etiaRs ef tl=ie reft.1eH Fi§ iAterleeks. (con~; ,11ued) GRAND GULF RevJsieR Ne.. *e Page 180 of 197
CQ11tro:l Rod: dP~RABlLIJ~ef~~1 f0g B :3.9,.5*
.*BASES *SURVEILLANCE R~Q~lREM~~TS The Surveillance Frequencies are controlled under the SR>3.~.~ ~ s~1. ls *ril9d_ifted .b.Y a N~t~. W~t 'alJoW.~ 7 .<tc1:;ys; a~t~r S urveilla nee \'lithdraw,~1. :of tile, control r99. to perform the ,Sut-,veJllailc~i~
Frequency Control l"ht~ ~:ckno~Jepg~s*. that. th,~ .contrqf ro.d mu.st fi.r~l: l;)f Program.
\~iJhd.tawn .b,~fo.re p~rforniance, J)f the SurveiJlafl<:e, *ahd th~reft>t~ :avoids, *potehtial cqnflfcts 1i1Jtp *SR 3/0,.3, Jinij.
SR.3..;.Q *..4:. REFERENCES l.. io CFR .50, Append lx A, . GDC 29 ~
- 2. UFSAR, *sect1on- 15.4.1.1.
,GRAND GULF Re;iisi or-t Ne. o *-
Page 181 of 197
RPV: .Water Level - Irra:djafed Fue.l B '.3.9.6
~AS{S SURVEILLANCE SR 3.9~fr.1 (continued)
REQU_ t REM ENJS leye.l li.mHs the.* consequences o.f*. damaged fuel r.od~, wb:i:ch The Surveillance are postu"iated to resuft from a fuel h*andling <atc1dent ih Frequency is containment; {Ref. 2). controlled under the Surveillance ~Tl9.e FreC:fuefley ef 24 R~Ul°s is ~aseEl e.19 e~§iflqefi.19§ Ju.6.fiffiC~t.. Frequency Control a19e 1::f .eeflsfee\ocd acleeruate ifl vi.ew .ef tl'le la12*§¢ vei uffit
- ef
\J,ater ahd tt'le flOfflNl procedural COAtr'ols Ofl 1ial 1ie positi6fi*s, Program. ~i19.td~ fflake. s~.§191 fi ea~t l:l.flJ9l afl19ee level (;flcll9§CS ui9Ti lc.clY.
REF ER ENC E.S L Appendix B fo Regul atorY Gui de LJ83.; July 2000. 2~ U.FSAR,. Secticm 15. 7.4.~. 3.
- 4. N.UREG~Q831, *Suppl <=ment 6., Section l6A. 2.
5; 10 CFR 50.67, "Accident ~:ource Terrn;" GRAND GULF B 3.~-9-21 LDC 81050 Page 182 of 197
RPV Water Level - New Fuel or Control Rods B 3.9.7 BASES SURVEILLANCE SR 3.9.7.1 (continued) REQUIREMENTS met. Water at,the required level limits the consequ~nces The Surveillance of damaged fuel rods, which are postulated to result from a Frequency is fuel_ handling accident in containment (Ref. 2). controlled under the Surveillance The FrequeAcy of 24 hours is based OA eAgiAeeriAg judgmeAt Frequency Control aAd is coAsidered adequate iA view of the large volume of water aAd the Aormal procedural coAtrols oA valve positioAs, Program. which make sigA'ificaAt uAplaAAed level chaAges uAlikely. REFERENCES 1. Appendix B to Regulatory Guide 1.183, July 2000.
- 2. UFSAR, Section 15.7.4.
- 3. NUREG-0800, Section 15.0.1 .
*I
- 4. NUREG-0831, Supplement 6, Section 16.4.2.
- 5. 10 CFR 50. 67, "Accident Source Term."
GRAND GULF B 3.9-24 LDC 01050 Page 183 of 197
RHR- High Water Level B 3*.9.8 BASES ACTIONS B.l, B.2, B.3, and B.4 (continued) ensuring secondary containment is OPERABLE, one standby gas "' treatment subsystem is OPERABLE, and secondary containment isolation capability (i.e., at least one isolation valve and associated instrumentation in each associated penetration not isolated that is assumed to be isolated to mitigate radioactivity releases are OPERABLE or other acceptable administrative controls to assure isolation capability). This may be performed as an administrative check, by examining logs or other information, to determine whether the components ar~ out of service for maintenance or other reasons. It is not necessary to perform the Surveillances needed to demonstrate the OPERABILITY of the components. If, however, any required component is inoperable, then it must be restored to OPERABLE status. In this case, a surveillance may need to be performed to restore the component to OPERABLE status. Actions must continue until all required components are OPERABLE. C. l and C. 2 If no decay heat removal subsystem (RHR shutdown cooling subsystem or ADHRS) is in operation, an alternate method of coolant circulation is required to be established within 1 hour. The Completion Time is modified such that 1 hour is applicable separately for each occurrence involving a loss of.-coolant circulation. During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling subsystem or ADHRS), the reactor coolant temperature must be periodically monitored tp ensure proper functioning of the alternate method. The once per hour Completion Time is deemed appropriate. SURVEILLANCE SR 3.9.8.1 REQUIREMENTS This Surveillance demonstrates that the RHR shutdown cooling subsystem or ADHRS is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability. continued The Surveillance Frequency is controlled under the Surveillance GRAND GULF B 3.9-28 Frequency Control LDC 07019 Program. Page 184 of 197
RHR - High Water Level B 3.9.8 BASES ~(continued) SURVEILLANCE REQUIREMENTS SR 3.9'.8.1 J27 (CORti m.ted) sufficieRt iR view of other visual aAd audible iAdicatioAs available to the operator for monitoring the RHR subsystem in the control room.
/
__,-----1 ( continued)
~~~~~~~~~~~~~~~~~~~~~- 1 REFERENCES AEEM-90/0135, MAEC-90/0236, ER-GG-2007-0028 ~ \I
<Move to page B 3.9-28c after SR 3.8.9.2 and include double line at the end.> GRAND ,GULF B 3.9-28a LDC 07019 Page 185 of 197
RHR- High Water Level B 3.9.8 BASES SURVEILLANCE SR 3.9.8.2 REQUIREMENTS (continued) potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and trending of the The Surveillance results should be sufficient to assure system OPERABILITY during the Frequency is Surveillance interval. controlled under the Surveillance The 31 day FFequeAey talEes iAto eonsidemtion the gFadual natuFe of gas Frequency Control aeeumulation in the RHR Shutdov.m Cooling System piping and the Program. The pmeeduml eontmls gm,eming system opemtion. Surveillance Frequency may vary by location susceptible to gas accumulation GRAND GULF B 3.9-28c LBDGR 14044 Page 186 of 197
RHR - Low Water Level 8 3.9.9 BASES (continued) SURVEILLANCE SR 3.9.9.1 REQUIREMENTS This Surveillance demonstrates that one RHR shutdown cooling The Surveillance subsystem or ADHRS is in operation and circulating reactor coolant. The Frequency is required flow rate is determined by the flow rate necessary to provide controlled under the sufficient decay heat removal capability. The Frequency of 12 hours is Surveillance sufficient in *,imu of other visual and audible indications available to the Frequency Control operator f.or monitoring the Rl=IR subsystem in the control room. Program. SR 3.9.9.2 RHR Shutdown Cooling System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR shutdown cooling subsystems and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel. Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions. The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Shutdown Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. l(continued) 1----~ GRAND GULF B 3.9-33 LSDGR 14044 Page 187 of 197 .
RHR - Low W~tcr Level I B 3.9.9 SR 3.9.9.2 (continued) BASES (eeAtinucel) RHR Shutdown Cooling System locations susceptible to gas accumulation arc monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations Surveillance
, in the same system flow path which arc subject to the same gas intrusion ,
Requirements mechanisms may be verified by monitoring a representative subset of susceptible locations. Monitoring may not be practical for locations that arc inaccessible due to radiological or environmental conditions, the plant The Surveillance configuration, or personnel safety. For these locations alternative Frequency is methods (e.g., operating parameters, remote monitoring) may be used to controlled under the monitor the susceptible location. Monitoring is not required for susceptible Surveillance locations where the maximum potential accumulated gas void volume has Frequency Control been_ evaluated and determined to not challenge system OPERABILITY. Program. The The accuracy of the method used for monitoring the susceptible locations Surveillance and trending of the results should be sufficient to assure system Frequency may vary OPERABILITY during the Surveillance interval. by location , susceptible to gas The 31 elay FrequeRrY talms iAte eoAsielqmtioA the graelual Aat.ure of gas accLJmulation aeeumulatioA iA the RHR Shutelm.-m GooliAg Systeffl 13ipiAg aAel the, proeedural controls gmterning system operatioA. REFERENCES _AECM-90/0135., MAEC-90/0236, ER-GG-2007-0028. GRAND GULF B 3.9-34 LBDCR 14044 Page 188 of 197
Reactor Mode Switch Interlock Testing B 3.10.2 1 BASES ( continued) ACTIONS A.1, A.2, A.3.1, and A.3.2 These Required Actions are provided to restore compliance with the Technical Specifications overridden by this Special Operations LCO. Resrtoring compliance will also result in 1 exiting the Applicab ili ty of this Special Operations LCO. All CORE ALTERATIONS except control rod insertion, if~in progress, are immediately suspended in accordance with Required Action A.1, and all insertable control rods in core cells that contain one or more fuel assemblies are fully inserted within 1 hour, in accordance with Required Action A.2. This will preclude potential mechanisms that could lead to criticality. Suspension of CORE ALTERATIONS shall not preclude the completion of movement of a component to a safe condition. Placing the reactor mode switch in the shutdown position will ensure that all inserted control rods, remain inserted and result in operation in accordance with Table 1.1-1. Alternatively, if in MODE 5, the reactor mode switch may be placed in the refuel position, which will also result in operating in accordance with Table 1.1-1. A Note is added to Required Action A.3.2 to indicate that this Required Action is not applicable in MODES 3 and 4, since only the shutdown position is allowed in these MODES. The allowed Completion Time of 1 hour for Required Actions A.2, A.3.1, and A.3.2 provides sufficient time to normally insert the control rods and place the reactor mode switch in the required position, based on operating experience, and is acceptable given that all operations that could increase core* reactivity have been suspended. SURVEILLANCE SR 3.10.2.1 and SR 3.10.2.2 REQUIREMENTS Meeting the requirements of this Special Operations LCO maintains operation consistent with or conservative to operating with the reactor mode switch in the shutdown position (or the refuel position for MODE 5). The functions of the reactor mode switch interlocks that are not in effect, due to the testing in progress, are adequately compensated for by the Special Operations LCO requirements. The administrative controls are to be periodically verified to ensure that the operational requirements continue to be met. To provide additional assurance that control rods are not withdrawn, SR 3.10.2.1 is performed by two licensed operators or other.technically qualified members* of the unit technical staff. The ~urueillanoes perforJfled at the 12 hour and 24 hm.1r (oontinued) The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. GRAND GULF B 3.10-8 geuision }lo 2 Page 189 of 197
Reactor Mode Switch Interlock Testing B 3.10.2
*,,~
BASES~~ aURFE:ILLNJCE ~ 3 10 2.1 and ag 3.10 2.2 (oontinuod) ggQurnE:D4Kt,JTa Froquonoios are intended to prouido appropriate assuranoo that oaoh operating shift is aHaro of and :uorify ooFBplianoo uith the.so apooial Operations LCO roquiroFBonts REFERENCES 1. UFSAR, Section 7.2.1.1.
- 2. UFSAR, Section 15.4.1.1.
GRAND GULF B 3.10-9 go:uision liJo. 0 Page 190 of 197
9ingle Control Rod WithdrawalCHot Shutdown B 3.10.3 BASES ACTIONS A.1 (continued) added, which clarifies that this Required Action is only applicable if the requirements not met are for an affected LCO. A. 2 . 1 and A. 2 . 2 Required Actions A.2.1 and A.2.2 are alternative Required Actions that can be taken instead of Required Action A.1 to restore compliance with the normal MODE 3 requirements, thereby exiting this Special Operations LCO's Applicability. Actions must be initiated immediately to insert all insertable control rods. Actions must continue until all such control rods are fully inserted. Placing the reactor mode switch in the shutdown position will ensure that all inserted rods remain inserted and restore operation in accordance with Table 1.1-1. The allowed Completion Time of 1 hour to place the reactor mode switch in the shutdown position provides sufficient time to normally insert the control rods. SURVEILLANCE SR 3.10.3.1, SR 3.10.3.2, and SR 3.10.3.3 REQUIREMENTS The other LCOs made applicable in this Special Operations LCO are required to have their Surveillances met to establish that this Special Operations LCO is being met. If the local array of control rods is inserted and disarmed while the scram function for the withdrawn rod is not available, periodic verification in accordance with SR 3.10.3.2 is required to preclude the possibility of criticality. SR 3.10.3.2 has been modified by a Note, which clarifies that this SR is not required to be met ~f SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements, The Surveillance since *sR 3.10.3.2 demonstrates that the alternative Frequencies are LCO 3.10.3.d.2 requirements are satisfied. Also, controlled under the SR 3.10.3.3 verifies .that all control rods other than the Surveillance ~control rod being withdrawn are fully inserted. Tho 24 hour Froquonoy is aoooptablo booauso of tho adrainistrativo Frequency Control oontrols on oontrol rod Hithdrmmls, tho *protootion afforded Program. by tho LCOs inuoluod, and hardimro intorlooks that prooludo additional
)
oontrol rod HithdraHals. (continued) GRAND GULF B 3.10-13 Revision Wo. 0 Page 191 of 197
Single Control Rod WithdrawalCCol d Shutdown B 3.10.4 BASES (continued) SURVEILLANCE SR 3.10.4.1, SR 3.10.4.2, SR 3.10.4.3, and SR 3.10.4.4 REQUIREMENTS The other LCOs made applicable by this Special Operations LCO are required to have their associated Surveillances met to establish that this Special Operations LCO is being met. If the local array of control rods is inserted and disarmed while the scram function for the withdrawn rod is not available, *periodic verification is required to ensure that the possibility of criticality remains precluded. Verification that all the other control rods are fully inserted is required to meet the SDM requirements. Verification that a control rod withdrawal block has been inserted ensures that no other control, rods can be The Surveillance Frequencies are controlled under the Surveillance Frequency Control an additional Gon:l::rol rod HithdraHal Program. SR 3.10.4.2 and SR 3.10.4.4 have been modified by Notes, which clarify that these SRs are not required to be met if the alternativ~ requirements demonstrated by SR 3.10.4.1 are satisfied. REFERENCES 1. UF~AR, Section 15.4.1.1. GRAND GULF B 3.10-19 Revision "No. 0 Page 192 of 197
Single CRD Removal C Refueling B 3.10.5 BASES (continued) ACTIONS A.l, A.2.1, and A.2.2 If one or more of th~ requirements of this Special Operations LCO are not met, the immediate implementation of these Required Actions restores operation consistent with the normal requirements for failure to meet LCO 3.3.1.1, LCO 3.3.8.2, LCO 3.9.1, LCO 3.9.2, LCO 3.9.4, and LCO 3.9.5 (i.e., all cont~ol rods inserted) or with the allowances of this Special Operations LCO. The Completion Times for Required Action A.l, Required Action A.2.1, and Required Action A.2.2 are intended to require these Required Actions
\be implemented. in a very short time* and carried through in an expeditious manner to either initiate action to restore the CRD and insert its control rod, or initiate action to restore compliance with this Special Operations LCO.
Actions must continue until either Required Action A.2.1 or Required Action A.2.2 is satisfied. SURVEILLANCE SR 3.10.5.1, SR 3.10.5.2, SR 3.10.5.3, SR 3~10.5.4, and REQUIREMENTS SR 3.10.5.5 Verification that all the control rods, other than the control rod withdrawn for the removal of the associated CRD, are fully inserted is required to ensure the SDM is within limits. Verification that the local five by five array of control rods other than the control rod withdrawn for the* removal of the associated CRD, is inserted and disarmed electrically or hydraulically, while the scram function for the withdrawn rod is not available, is required to ensure that the possibility of criticality remains precluded. Verification that a control rod withdrawal block has been inserted ensures that no other control rods can be inadvertently withdrawn under conditions when position indication instrumentation is inoperable for the withdrawn control rod. The Surveillance for LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," which is made applicable by this Special Operations LCO, is required in order to establish that this Special Operations LCO is being met. Verification that no The Surveillance other CORE ALTERATIONS are being made is required to ensure the assumptions of the safety analysis are satisfied. Frequencies are controlled under the Surveillance Periodic verification of the administrative controls Frequency Control Program. established by this Special Operations LCO is prudent to preclude the possibility of an inadvertent criticality. ~{ (continued) GRAND GULF B 3.10-23 Rouision '°No. 1 Page 193 of 197
Single CRD Removal C Refueling B 3.10.5 BASES~ aUgVE;ILLP.JJCE: ~ 3.10.5.1, ag 3.10.5.2, ag 3.10.5,3, ag 3 10.5.4, and gE;QUrnE:D4Kl?JTa ~ 3,10 5.5 (continued) 24 hour Freq:Hency is acceptable, given the administrative controls on control rod removal and harduare interlocks to blook an additional oontrol rod uithdraual. REFERENCES 1. UFSAR, Section 15.4.1.1. GRAND GULF B 3.10-24 Revision DJo. 0 I Page 194 of 197
Multiple Control Rod WithdrawalCRefueling
\ B 3.10.6 BASES (continued)
APPLICABILITY Operation in MODE 5 is controlled by existing LCOs. The exceptions from other LCO requirements (e.g., the ACTIONS of LCO 3.9.3, LCO 3.9.4 or LCO 3.9.5) allowed by this Special Operations LCO are appropriately controlled by requiring all fuel to be removed from cells whose "full in" indicators are allowed to be bypassed. ACTIONS A.1, A.2, A.3.1, and A.3.2 If one or more of the requirements of this Special Operations LCO are not met, the immediate implementation of these Required Actions commences activities which will
*restore operation consistent with the normal requirements
- for refueling (i.e., all control rods inserted in core cells containing one or more fuel assemblies) or with the exceptions granted by this Special Operations LCO. The Completion Times are intended to require that these Required Actions be implemented in a very short time and carried through in an expeditious manner.
SURVEILLANCE SR 3.10.6.1, SR 3.10.6.2: and SR 3.10.6.3 1 REQUIREMENTS The Surveillance Periodic verification of the administrative controls established by this Special Operations LCO-is prudent to Frequencies are preclude the possibility of an inadvertent criticality. ~ controlled under the 24 hour Frequenoy is aooeptable, given the administrative Surveillance oontrols on fuel assembly and oontrol rod roifloual, and takes Frequency Control into aooount other indioations of oontrol rod status auailablo in tho control rooH-1. Program. REFERENCES 1. UFSAR, Section 15.4.1.1. GRAND GULF B 3.10-27 Revision T?Jo. 0 Page 195 of 197
r SOM Test-Refueling s 3.Jo**~*s*
-sORVEILLANGE :sR 3 *.10.8.L, SR *3.-10.8.2 .and* SR a:.10.S.3 REQUIREMENTS Ttre other. LCOs mad*e appli c~:ble- in_ !hi}. :Spet,5'ai Qperati <rns
µCO' are> require~f to h'aver applit::ab]_e §urve.i)) ~nces lllet to-estab1i sh thatthi ~ Special. Qp(aratlo~,s- :LCff ts :bejng met-.
.HQVJev~r, the. corit rol *. tod. ~~tthd_raw~f $equ~nc~-s :ciurtn,g tes\s. ma,Y be enfqrc:edby -~he RPC: (~CO 3. :.3.~2}1, .Fun*ctio.n Jb, the SQM
- MODE 2' r~qulre,n~_nts} or by,-*~, s*eco_nd _lfc:¢nsed. C>perator o~
other .qualified: m:mber of the techntcal "staff.'* A~: noted, e*ither the app-li.cable SRs for._the :RPC {Lto::,3 .3\.2:A) must be
- sati sft~d accordtng to the app 11 cab1 e Fr-eque:nctes (SR :3.10.8.2},or ttle'. :p~oper: movement: of, :-<:ontrol :rods must b~ verified. {SR 3.lO~B.3) ** Thi~ 'latter' verlfic,atipn, (f*.e~.:,
SR 3.)o.:a .* 3} mµst .beperf9rm~d µur-tngdlritro) :rQq rne>Ventijnt
- tQ preVE!rlt ':d~via1::i <>}1S .* frQm *t~f spe'clfied s.equence. Th_es~ ,
$tn"Ve'i ]lances provid-e* adequate assuran:<:~ thc1t the speqified test sequence. is- be.ing*- followed.
SR 3 .10 .8.4 The Surveillance Peri.odfc V~r:iftcatton .of {be admfntstrattVf ¢on'tt6ls .* Frequency is
- e~1ab1 ished by *thi~ 1CO will. ensure that 'the_rea:ctor ts_
controlled under the operated. withtn th~ bqunds of the safety analysJ~ ... _+he,
- Surveillance 12
- hellr Fre~t-Jeft.ey ts iAtended tfJ pravta*e .appreprii ate . -. _.
Frequency Control :ass1:1rafiee
- that. _each eperati fl§ shlft is awaFe ef' ana veri fl.es Program. eom~l 1a*Aee ~iith these .Speei al Spetati ans -~<;'() req~1 remer.ft*s.
SR :3.10.'8.5 A...¢oupl. tn.g -~.*-erif.1c.at*i* on such as dest::rtb.ed.in th.e ,Ba.~_** s* e*.* s. tor ~. SR,3.1.3~5 ,s per-formed to ensure t-he cont.rol rod TS I' connected to the. co*ntrol rod drive_ mech*anism, andi will * - p:erfo.nn Hs :1 ntended '.functfoll :wh*en. n~c~ssary~ . The: verific~tfon ; s required to be ferfor,n~~ a.nY tJfoe a c:cmtr61 rod ts wfth.tirawn t.o. th~ l'fuJJ. out no.t¢h posiJi'tl.1' or 'priQr 11 toc:ontrtH :ro_d pr CRD~ System that :cQuld r1ffecl coupJjng,.
*declarlng ttte :control 'rog OPERABLE after ~ork ()Jl :t~e Thts
'Frequency* is ~c-ceptable,. considering }he_ *.low P.rob~bility that a. :control .rod* wi 11 become uncoupled ~herf tt ts not.
being .moved. as \flell *as operatfog e>eperi¢o¢e related to
µncotip]i~Q -vehts~ * - * * - * * ***. - *
- :fconttnued}
GRAND GULF 83.10-36 Page 196 of 197
SOM test~Refu~l1frg
*s 3.lo~s*
SURVEILLANCE SR l}l0.8.6 REQUtREME.Nts
...**(contiriµe,dJ C~O c:p~r:glJj~f W~.t~f hEiac,ief pre~sur¢ Vg(ific:a{itj~ ifs p~f'fotS11ed to* e:ns~re. the motive force. ;s :avajlable* to*. s~ranf th~. contra l rQcJ,s **.ir.a .th~* .eve:nt of '.a* s~:'f*an1 . *~lgna1.* .
- A.mJnJmµm ac:c:ti.m'µl~tor The Surveillance pressur~, is Sp~pifi ijds ~elow Which. .th~ :.capability .Qf th~
atcumuTa.tor ,t9 .perform> ils lntend.ed, .ftmcti on becomes Frequency is d~graoed and: the *accumul ~tQr, t~ con~idered inoperabl):. The controlled under the minimtJm acc.umulat'or pr_E!s:~ure. of . lp20 psJg .ls,*:Wel 1. below, the Surveillance expected pressure* of *1750 psi g. Jl:te .7 <:lay Jl"eflt1et1ey has . Frequency Control aeeR sha:w'A te Jn: c1ceeptaele thl°aug~ epet*af1li§ *expetie*Ree artd . Program. ~akes 'inta actei:nrt indicatier-t:s* ..avaAlaeJe ifl 1:he :eefff):!el * *
~ .
- REfER~NC.ES 1. *N.EDE.-24011-P~~,.* ':"G~n.era] Ele¢trf~ .Sttu1~~~tj: /'*PPltc~tion fo,t* RE!cictor Fuel, :G~STAR :Il" {l~test approve!~. . . .
revfsipri). ** 2;.. Lett.er, l ..A... pickens (BWR0GJ1<> G. C. laina$. (NRCJ,.
Amendment 17 to .General Electric Licen*sing Topical' Report N'EDE~240ll-J>.:.Ax'i Aug~st 15-, 1986*. . .
\
GRAND GULF B S~l0-37 Page 197 of 197
Attac hmen t 6 to GNR0-2018/00013 Propo sed No Signi ficant Hazards Cons iderat ion (2 pages)
,Attachment 6 -Proposed No Significant Hazards Consideration GNR0-2018/00013 Description of Amendment Request: The change requests the adoption of an approved change to the standard technical specifications (STS)for General Electric Plants, BWR/6 (NUREG-1434), to allow relocation of specific TS surveillance frequencies to a licensee-controlled program. The proposed change.is described in Technical Specification Task Force (TSTF) Traveler, TSTF-425, Revision 3 (Rev. 3) (ADAMS Accession No. M.L090850642) related to the Relocation of Surveillance Frequencies to Licensee Control-RITSTF lnit.iative 5b\and was described in the Notice of Availability published in'the Federal Register on July 6, 2009 (74 FR 31996). The proposed changes are consistent with NRG-approved Industry/Technical Specification Task Force (TSTF) Traveler, TSTF-425, Rev. 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b." The proposed change relocates surveillance frequencies to a licensee-controlled program, the SFCP. This change is applicable to *
. licensees using probabilistic risk guidelines contained in NRG-approved NEI 04-10, "Risk- .
Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," (ADAMSAccessio n No. ML071360456). Basis for proposed no significant hazards consideration: As required by 10 CFR 50.91 (a), the Entergy's analysis of the issue of no significant hazards consideration is1 presented below: * , . *
- 1. Does the proposed change involve a significantincrease in the probability or
- consequences of any accident previously evaluated?
Response: No. The proposed change relocates the specified frequencies for periodic surveillance requirements to licensee control under a new Surveillance Frequency Control Program. Surveillance frequencies are not an initiator to any ac*cident previously evaluated. As a result, the probability of any accident previously evaluated is not significantly increased. The systems and components required by the technical specifications for which the surveillance frequencies are relocated are still required to be operable, meet the acceptance criteria for the surveillance requirements, and be capable of performing any mitigation function assumed in the accident analysis. As .a result, the consequences of any accident previously evaluated are not significantly increased. 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 previously evaluated?
Response: No. No new or different accidents result from utilizing the proposed change. The changes do not involve a physical alteration of the plant (i.e., no new or different type of equipment will be installed) or a change in the methods governing normal pl~nt operatio*n. In addition, the changes do not impose any new or different requirements. The changes do not alter assumptions made in the safety analysis. The proposed changes are consistent with the safety analysis assumptions and current plant operating practice. Page 1 of 2
-Proposed No Significant Hazards Consideration GNR0-2018/00013 Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.
- 3. Does the proposed change involve a significant reduction in the margin of safety?
F3esponse: No. The design, operation, testing methods, and acceptance criteria for systems, structures, and components (SSCs ), specified in applicable codes and standards (or alt$rnatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including*the t'inal safety analysis report and bases to TS), since these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. To evaluate a change in the relocated *surveillance frequency, Entergy will perform a probabilistic risk evaluation using the guidance contained in NRC approved NEI 04-10, Rev. 1 in accordance with the TS SFCP. NEI 04-10, Rev. 1, methodology provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies consistent with Regulatory Guide 1.177. Therefore, the proposed changes do not involve a significant reduction in a margin of safety. Based upon the reasoning presented above, licensee concludes that the requested change does not involve a significant hazards consideration as set forth in 10 CFR 50.92(c), Issuance of amendment. '- Page 2 of 2
Attachment 7 to GNR0-2018/00013 Grand Gulf Nuclear Station (GGNS), Unit 1, TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference . (35 pages)
- Grand Gulf Nuclear _Station, Unit 1 {GGNS) TS Surveillance Requirements {SRs) to NUREG-1434 SRs Cross,;.Reference GNR0-2018/00013 Legend:
GGNS SR Frequency Identified for Relocation Not Included in TSTF-425 = ;r~Mi;§(1~ SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR
- GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency License Number Surveillance) TSTF-425 Amendment Section 3.1, Reactivity Control Systems SR 3.1.3.1 SR 3.1.3.1 Determine the position of each control 24 hours Yes Yes rod.
SR 3.1.3.2 NA DELETED None Yes (7 day NA (SR 3.1.3.2 in Frequency) TSTF-425) SR 3.1.3.3 SR 3.1.3.2 Insert each withdrawn control rod at least 31 days (Note: Applies to Yes Yes (SR 3.1.3.3 in one notch. partially withdrawn rod - TSTf-425) whereas NUREG-1434 applies to each withdrawn rod (partial and full). See TSTF-475) SR 3.1.4.2 SR 3.1.4.2 Verify, for a representative sample, each 200 days cumulative Yes (120 days Yes tested control rod scram time is within the operation in MODE 1 cumulative ... ) limits of Table 3.1.4-1 with reactor steam dome pressure;;:: 950 psig. SR 3.1.5.1 SR 3.1.5.1 Verify each control rod scram 7 days Yes Yes accumulator pressure ... SR 3.1.6.1 SR 3.1.6.1 Verify all Operable control rod_s comply 24 hours Yes Yes with BPWS. SR 3.1.7.1 SR 3.1.7.1 Verify available volume of sodium 24 hours Yes Yes pentaborate solution is ... SR 3.1.7.2 SR 3.1.7.2 Verify temperature of sodium pentaborate- 24 hours Yes Yes solution is ... Page 1 of 35
- Grand Gulf Nuclear Station {GGNS}, Unit 1 TS Surveillance Requirements {SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev. 4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment NA SR 3.1.7.3 [Verify temperature of pump suction NA Yes NA piping is within the limits of [Figure 3.1. 7-1].
SR 3.1.7.4 SR 3.1.7.4 Verify continuity of explosive charge. 31 days Yes Yes SR3.1.7.5 SR 3.1.7.5 Verify the percent weight of sodium 31 days Yes (31 day Yes (31 day pentaborate in solution is s 9.5%. Frequency only) Frequency AND only) Once with 24 hours after water or boron ... AND Once within 24 hours after solution ... SR 3.1.7.6 SR 3.1.7.6 Verify each SLC subsystem manual, 31 days Yes Yes power operated, and automatic valve ... is in the correct position, or can be aligned to the correct position. SR 3.1.7.7 SR 3.1.7.7 Verify each pump develops a flow rate ~ In accordance with lnservice Yes (92 day No 41.2 gpm at a discharge pressure ~ 1370 Testing Program Frequency only - psig. i.e., does not apply if the Frequency being used is the IST Program) SR 3.1.7.8 SR 3.1.7.8 Verify flow through one SLC subsystem 24 months on a Staggered Yes Yes from pump into reactor pressure vessel. Test Basis Page 2 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Proposed Rev. 4SR (NUREG-1434 Description if no GGNS modified by Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.1.7.10 SR 3.1.7.9 Verify piping between the storage tank Once within 24 hours after Yes ([18] month No and pump suction is not blocked. solution temperature is Frequency only) restored ...
SR 3.1.8.1 SR 3.1.8.1 Verify each SDV vent and drain valve is 31 days Yes Yes open. '-- SR 3.1.8.2 SR 3.1.8.2 Cycle each SDV vent and drain valve to 92 days Yes Yes the fully closed and fully open position. SR 3.1.8.3 SR 3.1.8.3 Verify each SDV vent and drain valve: 24 months Yes Yes
- a. Closes in ...- ; and
- b. Opens when ...
Section 3.2, Power Distribution Limits SR 3.2.1.1 SR 3.2.1.1 Verify all APLHGRs are less than or equal Once with 12 hours ... Yes (24 hours Yes (24 hours to the limits specified in the COLR. thereafter thereafter AND Frequency only) Frequency only)
-~ 24 hours thereafter SR 3.2.2.1 SR 3.2.2.1 Verify all MCPRs are greater th_an or Once with 12 hours ... Yes (24 hours Yes (24 hours equal to the limits specified in the COLR. thereafter thereafter AND Frequency only) Frequency only) 24 hours thereafter - SR 3.2.3.1 SR 3.2.3.1 Verify all LHGRs are less than or equal to Once with 12 hours ... Yes (24 hours Yes (24 hours the limits specified in the COLR. thereafter thereafter AND Frequency only) Frequency only) 24 hours thereafter NA STS 3.2.4, Average Power Range Monitor (APRM) Gain and Setpoints (Optional), and associated SRs are NA for GGNS Page 3 of 35 - Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs
- Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Proposed -
Rev.4SR (NUREG-1434 Description if no GGNS modified by Number Frequency Number Surveillance) TSTF-425 License Amendment Section 3.3, Instrumentation SR 3.3.1.1.1 SR 3.3 ..1.1.1 Perform Channel Check. 12 hours Yes . Yes SR 3.3.1.1.2 SR 3.3.1.1.2 Verify the absolute difference between 7 days Yes Yes the average power range monitor (APRM) channels and the calculated power. .. NA - SR 3.3.1.1.3 Adjust the flow control trip reference card NA Yes (7 day NA to conform to reactor flow. Frequency) SR 3.3.1.1.3 SR 3.3.1.1.4 Perform Channel Functional Test. 7 days Yes Yes SR 3.3.1.1.4 SR 3.3.1.1.5 Perform Channel Functional Test. 7 days Yes Yes SR 3.3.1.1.7 SR 3.3.1.1.6 Calibrate the local power range monitors. 2000 MWD!f average core Yes (1000 Yes exposure MWD!f average core exposure Frequency) SR 3.3.1.1.8 SR 3.3.1.1.7 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.1.1.9 SR 3.3.1:1.8 Calibrate the trip units. 92 days Yes Yes SR 3.3.1.1.10 SR 3.3.1.1.9 Perform Channel Calibration. 24 months -Yes Yes SR 3.3.1.1.11 SR 3.3.1.1.10 . Perform Channel Functional Test. 24 months Yes Yes SR 3.3.1.1.12 SR 3.3.1.1.11 Perform Channel Calibration. 24 months Yes Yes
~
NA SR 3.3.1.1.12 Verify the APRM Flow Biased Simulated NA Yes NA Thermal Power - High time constant is within the limits specified in the COLR. SR 3.3.1, 1.13- SR 3.3.1.1.13 Perform Logic System Functional Test. 24 months Yes Yes
- Page 4 of 35
-. Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.3.1.1.14 SR 3.3.1.1.14 Verify Turbine Stop Valve Closure, Trip 24 months Yes Yes Oil Pressure - Low and Turbine Control Valve Fast Closure Trip Oil Pressure -
Low Functions are not bypassed when Thermal Power is~ 35.4% RTP. SR 3.3.1.1.15 SR 3.3.1.1.15 Verify the RPS Response Time is within 24 months on Staggered Yes Yes limits. Test Basis SR 3.3.1.2.1 SR 3.3.1.2.1
- Perform Channel Check. 12 hours Yes Yes SR 3.3.1.2.2 SR 3.3.1.2.2 Verify an Operable SRM *detector is 12 hours Yes Yes located in ...
SR 3.3.1.2.3 SR 3.3.1.2.3 Perform Channel Check. 24 hours Yes Yes Page 5 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.3.1.2.4 SR 3.3.1.2.4 Verify count rate is ... - 12 hours during Core Yes (both Yes (both Alterations Frequencies) Frequencies)
AND 24 hours NA SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST NA Yes NA [and determination of signal to noise ratio]. SR 3.3.1.2.5 SR 3.3.1.2.6 Perform Channel Functional Test. 31 days Yes Yes SR 3.3.1.2.6 SR 3.3.1.2. 7 - Perform Channel Calibration. 24 months Yes Yes SR 3.3.2.1.1 SR 3.3.2.1.1 Perform Channel Functional Test 92 days Yes Yes SR 3.3.2.1.2 SR 3.3.2.1.2 Perform Channel Functional Test 92 days Yes *Yes SR 3.3.2.1.3 SR 3.3.2.1.3 Perform Channel Functional Test 92 days Yes Yes SR 3.3.2.1.4 SR 3.3.2.1.4 Perform Channel Functional Test 92 days Yes - Yes SR 3.3.1.2.5 SR 3.3.1.2.5 Calibrate the low power setpoint trip units. 92 days Yes Yes SR 3.3.1.2.6 SR 3.3.1.2.6 Verify the RWL high power Function is 92 days Yes Yes not bypassed ... SR 3.3.2.1. 7 SR 3.3.2.1. 7 Perform Channel Calibration. 184 days Yes Yes SR 3.3.2.1.8 SR 3.3.2.1.8 Perform Channel Functional Test. 24 months Yes Yes SR 3.3.3.1.1 SR 3.3.3.1.1 Perform Channel Check. 31 days* Yes Yes SR 3.3.3.1.3 SR 3.3.3.1.2 Perform Channel Calibration. 24 months Yes Yes SR 3.3.3.2.1 SR 3.3.3.2.1 Perform Channel Check for each required 31 days Yes Yes instrumentation channel ... Page 6 of 35
- Grand Gulf Nuclear Station {GGNS), Unit 1 TS Surveillance Requirements {SRs) to NUREG-1434 SRs Cross-Reference ------
GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Proposed Rev.4SR (NUREG-1434 Description if no GGNS modified by Number Frequency License Number Surveillance) TSTF-425 Amendment SR 3.3.3.2.2 SR 3.3.3.2.2 Verify each required controLcircuit and 24 months Yes Yes transfer switch is capable ... SR 3.3.3.2.3 SR 3.3.3.2.3 Perform Channel Calibration for each 24 -months Yes Yes required instrumentation channel. .. SR 3.3.4.1.1 SR 3.3.4.1.1 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.4.1.2 SR 3.3.4.1.2 Calibrate the trip units. 92 days Yes Yes SR 3.3.4.1.3 SR 3.3.4.1.3 - Perform Channel Calibration. The 24 months Yes Yes Allowable Value ... SR 3.3.4.1.4 SR 3.3.4.1.4 Perform Logic System Functional Test... 24 months Yes Yes SR 3.3.4.1.5 SR 3.3.4.1.5 Verify TSV Closure, Trip Oil Pressure - 24 months Yes Yes Low and TCV Fast Closure, Trip Oil Pressure - Low Functions are not bypassed ... SR 3.3.4.1.6 SR 3.3.4.1.6 Verify the EOC-RPT Systern Response 24 months on a Staggered Yes Yes Time is within limits. Test Basis SR 3.3.4.1. 7 SR 3.3.4.1. 7 Determine RPT breaker interruption time. 60 months Yes Yes SR 3.3.4.2.1 SR 3.3.4.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.4.2.2 SR 3.3.4.2.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.4.2.3 SR 3.3.4.2.3 Calibrate the trip units. 92 days Yes Yes SR 3.3.4.2.4 SR 3.3.4.2.4 Perform Channel Calibration. The 24 months Yes Yes Allowable Value ... SR 3.3.4.2.5 SR 3.3.4.2.5 Perform Logic System Functional Test... 24 months Yes Yes SR 3.3.5.1.1 SR 3.3.5.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.5.1.2 SR 3.:3".5.1.2 Perform Channel Functional Test. 92 days Yes Yes Page 7 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference
- GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev. 4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License I
Amendment SR 3.3.5.1.3 SR 3.3.5.1.3 Calibrate the trip unit. 92 days Yes Yes SR 3.3.5.1.4 SR 3.3.5.1.4 Perform. Channel Calibration. 92 days Yes Yes SR 3.3.5.1.5 SR 3.3.5.1.5 Perform Channel Calibration. 24 months Yes Yes SR 3.3.5.1.6 SR 3.3.5.1.6 Perform Logic System Functional Test. 24 months Yes Yes NA SR 3.3.5.1. 7 Verify the ECCS Response Time is within NA Yes NA Refer to SR limits. 3.5.1.8 SR 3.3.5.2.1 SR 3.3.5.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.5.2.2 SR 3.3.5.2.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.5.2.3 SR3.3.5.2.3 Calibrate the trip units. 92 days Yes Yes SR 3.3.5.2.4 SR 3.3.5.2.4 Perform Channel Calibration. 24 months Yes Yes SR 3.3.5.2.5 SR 3.3.5.2.5
- Perform Logic System Functional Test. 24 months Yes Yes SR 3.3.6.1.1 SR 3.3.6.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.6.1.2 SR 3.3.6.1.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.1.3 SR 3.3.6.1.3 Calibrate the trip unit. 92 days \ Yes Yes SR 3.3.6.1.4 SR 3.3.6.1.4 Perform Channel Calibration. 92 days Yes Yes SR 3.3.6.1.5 SR 3.3.6.1.5 Perform Channel Calibration. 12 months Yes Yes SR 3.3.6.1.6 SR 3.3.6.1.6 Perform Logic System Functional Test. 18 months Yes Yes SR 3.3.6.1. 7 SR 3.3.6.1.5 Perform Channel Calibration.
- 24 months Yes Yes SR 3.3.6.1.8 SR 3.3.6.1.6 Perform Logic System Functional Test. 24 months Yes Yes Page 8 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference
- GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance .
Rev. 4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.3.6.1.9 SR 3.3.6.1. 7 Verify the Isolation System Response 24 months on a Staggered Yes Yes Time ... Test Basis SR 3.3.6.2.1 SR 3.3.6.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.6.2.2 SR 3.3.6.2.2 Perform-Channel Functional Test. 92 days. Yes Yes SR 3.3.6.2.3 SR 3.3.6.2.3 Calibrate the trip unit. 92*days Yes Yes SR 3.3.6.2.4 SR 3.3.6.2.4 Perform Channel Calibration. 12 months Yes Yes SR 3.3.6.2.5 SR 3.3.6.2.4 Perform Channel Calibration. 24 months Yes Yes SR 3.3.6.2.6 SR 3.3.6.2.5 Perform Logic System Functional Test. 24 months Yes Yes SR 3.3.6.2. 7 SR 3.3.6.2.6 Verify the Isolation System* Response 24 months on a Staggered Yes Yes Time ... Test Basis SR 3.3.6.3.1 SR 3.3.6.3.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.6.3.2 SR 3.3.6.3.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.3.3 SR 3.3.6.3.3 Calibrate the trip unit. 92 days Yes Yes SR 3.3.6.3.4 SR 3.3.6.3.4 Perform Channel Calibration 92 days Yes Yes SR 3.3.6.3.5 SR 3.3.6.3.5 Perform Channel Calibration. 24 months Yes Yes SR 3.3.6.3.6 SR 3.3.6.3.6 Perform Logic System Functional Test. 24 months Yes Yes SR 3.3.6.4.1 SR 3.3.6.4.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.6.4.2 SR 3.3.6.4.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.4.3 SR 3.3.6.4.3 . Calibrate the trip unit. 92 days 'Yes Yes Page 9 of 35
Attachment 7 - Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR I Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.3.6.4.4 SR 3.3.6.4.4 Perform Channel Calibration 92 days Yes Yes SR 3.3.6.4.5 SR 3.3.6.4.5 Perform Channel Calibration. 24 months Yes Yes SR 3.3.6.4.6 SR 3.3.6.4.6 Perform Logic System Functional Test. 24 months Yes - Yes / SR 3.3.6.5.1 SR 3.3.6.5.1 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.5.2 SR 3.3.6.5.2 Calibrate the trip unit. 92 days Yes Yes SR 3.3.6.5.3 SR 3.3.6.5.3 Perform Channel Calibration. The 24 months Yes Yes Allowable Value ... SR 3.3.6.5.4 SR 3.3.6.5.4 Perform Logic System Functional Test. 24 months Yes Yes NA SR 3:3.7.1.1 Perform Channel Check. NA Ye~ NA NA . SR 3.3.7.1.2 Perform Channel Functional Test. NA Yes NA
~
NA SR 3.3.7.1.3 Calibrate the trip units. NA Yes NA NA SR 3.3.7.1.4 Perform Channel Calibration. NA Yes NA SR 3.3.7.1.1 SR 3.3.7.1.5 Perform Logic System Functional Test. 24 months Yes Yes NA SR 3.3.8.1.1 Perform Channel Check. NA Yes NA
/
SR 3.3.8.1.1 SR 3.3.8.1.2 Perform Channel Functional Test. 31 days Yes Yes SR 3.3.8.1.2 SR 3.3.8.1.3_ Perform Channel Calibration. 18 months Yes Yes SR 3.3.8.1.3 SR 3.3.8.1.3 Perform Channel Calibration. 24 months Yes Yes SR 3.3.8.1.4 SR 3.3.8.1.4 Perform Logic System Functional Test. 24 months Yes Yes SR 3.3.8.2.1 SR 3.3.8.2.1 Perform Channel Functional Test. 184 days Yes Yes SR 3.3.8.2.2 SR 3.3.8.2.2 Perform Channel Calibration. The 24 months Yes Yes Allowable Value SR 3.3.8.2.3 SR 3.3.8.2.3 Perform a system functional test. 24 months Yes Yes Page 10 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs, Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveiilance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev. 4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment Section 3.4, Reactor Coolant System (RCS)
SR 3.4.1.1 SR 3.4.1.1 Verify recirculation loop jet pump flow 24 hours Yes Yes
- mismatch with both recirculation loops in operation is ...
SR 3.4.2.1 SR 3.4.2.1 Verify each FCV fails "as is" on loss of 24 months Yes Yes hydraulic pressure at the hydraulic unit. SR 3.4.2.2 SR 3.4.2.2 Verify average rate of each FCV 24 months Yes Yes movement is ... SR 3.4.3.1 SR 3.4.3.1 Verify at least two of the following criteria 24 hours Yes Yes (a, b, and c) are satisfied for each operating recirculation loop ... SR 3.4.4.1 SR 3.4.4.1 Verify the safety function lift setpoints of In accordance with the Yes (18 month No the required S/RVs are as follows ... lnservice Testing Program Frequency only - i.e., does not apply if the Frequency being used is the IST Program) SR 3.4.4.2 SR J.4.4.2 Verify each required relief function S/RV 24 months Yes Yes actuates on an actual or simulated aut9matic initiation signal. SR 3.4.4.3 SR 3.4.4.3 Verify each required S/RV relief mode In accordance with the Yes (18 months No actuator strokes when manually actuated. lnservice Testing Program ... on a Staggered Test Basis ... ) SR 3.4.5.1 SR 3.4.5.1 Verify RCS ... Leakage ... within limits. 12 hours Yes (Frequency Yes of 8 hours) Page 11 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.4.6.1 SR 3.4.6.1 Verify equivalent leakage of each RCS In accordance with the Yes (18 month No PIVis ... lnservice Testing Program Frequency only -
i.e., does not apply if the Frequency being used is the IST Program) SR 3.4.7.1 SR 3.4.7.1 Perform Channel Check of required 12 hours Yes Yes drywell atmospheric monitoring system. SR 3.4.7.2 SR 3.4.7.2 Perform Channel Functional Test of 31 days Yes Yes required leakage detection instrumentation. SR 3.4.7.3 SR 3.4.7.3 Perform Channel Calibration of required 24 months Yes Yes leakage detection instrumentation. SR 3.4.8.1 SR 3.4.8.1 Verify reactor coolant DOSE 7 days Yes Yes EQUIVALENT 1-131 specific activity is s 0.2 µ Ci/gm. SR 3.4.9.1 SR 3.4.9.1 Verify one RHR shutdown cqoling 12 hours Yes Yes subsystem or recirculation pump is operating. SR 3.4.10.1 SR 3.4.10.1 Verify one RHR shutdown cooling 12 hours Yes Yes subsystem or recirculation pump is operating. Page 12 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS S-urveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.4.11.1 SR 3.4.11.1 Verify: 30 minutes Yes Yes
- a. RCS pressure and RCS temperature ... , and
- b. RCS heatup and cooldown rates are ...
SR 3.4.11.5 SR 3.4.11.7 Verify reactor vessel flange and head 30 minutes Yes Yes flange temperatures ... SR 3.4.11.6 SR 3.4.11.8 Verify reactor vessel flange and head 30 minutes Yes Yes flange temperatures ... SR 3.4.11.7 SR 3.4.11.9 Verify reactor vessel flange and head 12 hours Yes Yes flange temperatures ... SR 3.4.12.1 SR 3.4.12.1 Verify reactor steam dome pressure ... 12 hours Yes Yes Section 3.5, Emergency Core Cooling Systems (ECCS) and Reactor Core Isolation Cooling (RCIC) System SR 3.5.1.1 SR 3.5.1.1 Verify, for each ECCS injection/spray 31 days Yes Yes subsystem, locations susceptible to gas accumulation are sufficiently filled with water. SR 3.5.1.2 SR 3.5.1.2 Verify each ECCS injection/spray 31 days Yes Yes subsystem manual, power operated, and automatic valve ... is in the correct position. SR 3.5.1.3 SR 3.5.1.3 Verify ADS accumulator supply pressure 31 days Yes Yes is ... Page 13 of 35
- Grand Gulf Nuclear Station {GGNS}, Unit 1 TS Surveillance Requirements {SRs} to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.5.1.4 SR 3.5.1.4 Verify each ECCS pump develops the In accordance with the Yes (92 day No specified flow rate with the specified total lnservice Testing Program Frequency only -
developed head ... i.e., does not apply if the Frequency being used is the IST Program) SR 3.5.1.5 SR 3.5.1.5 Verify each ECCS injection/spray 24 months Yes Yes subsystem actuates ... SR 3.5.1.6 SR 3.5.1.6 Verify the ADS actuates ... 24 months Yes Yes SR 3.5.1.7 SR 3.5.1.7 Verify each ADS valve relief-mode In accordance with the Yes (18 month No actuator strokes ... lnservice Testing Program Frequency on a on a Staggered Test Staggered Test Basis ... Basis ... ) SR 3.5.1.8 Refer to Verify the ECCS Response Time for the 24 months Yes (Refer to Yes STS SR 3.3.5.1. 7 HPCS System is within limits. STSSR 3.3.5.1.7) SR 3.5.2.1 SR 3.5.2.1 Verify, for each required low pressure 12 hours Yes Yes ECCS injection/spray subsystem, the suppression pool water level is ... SR 3.5.2.2 SR 3.5.2.2 Verify, for the required High Pressure 12 hours Yes Yes Core Spray (HPCS) System, the:
- a. Suppression pool water level is ... ; or
- b. Condensate storage tank water level is ...
Page 14 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License
~-! Amendment SR 3.5.2.3 SR 3..5.2.3 Verify, for each required ECCS 31 days Yes Yes injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.
SR 3.5.2.4 SR 3.5.2.4 Verify each required ECCS 31 days Yes Yes injection/spray subsystem manual, power operated, and automatic valve ... is in the correct position. SR 3.5.2.5 SR 3.5.2.5 Verify each required ECCS pump In accordance with the Yes (92 day No develops the specified flow rate with the lnservice Testing Program Frequency only - specified total developed head ... i.e., does not apply if the Frequency being used is the IST Program) SR 3.5.2.6 SR 3.5.2.6 Verify each required ECCS 24 months Yes Yes injection/spray subsystem actuates ... SR 3.5;3.1 SR 3.5.3.1 Verify the RCIC System locations 31 days Yes Yes susceptible to gas accumulation are sufficiently filled with water. SR 3.5.3.2 SR 3.5.3.2 Verify each RCIC System manual, power 31 days Yes Yes operated, and automatic valve ... is in the correct position. SR 3.5.3.3 SR 3.5.3.3 Verify, with RCIC steam supply pressure 92 days Yes Yes s 1045 psig and ~ 945 psig ... the RCIC pump can develop a flow rate ... Page 15 of 35
__ Attachment 7 - Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance} TSTF-425 License Amendment i SR 3.5.3.4 SR 3.5.3.4 Verify, with RCIC steam supply pressure 2;4months Yes Yes s 165 psig and ~ 150 psig ... the RCIC pump can develop a flow rate ... SR 3.5.3.5 SR 3.5.3.5 Verify the RCIC System actuates ... 24 months Yes Yes Section 3.6, Containment Systems SR 3.6.1.2.2 SR 3.6.1.2.2 Verify primary containment air lock seal ?days Yes Yes air flask pressure ... - SR 3.6.1.2.3 SR 3.6.1.2.3 Verify only one door in the primary 24 months Yes Yes containment air lock can be opened at a time. SR 3.6.1.2.4 SR 3.6.1.2.4 Verify, from an initial pressure of 90 psig, 24 months Yes Yes the primary containment air lock seal pneumatic system pressure does not decay at a rate equivalent to ... NA SR 3.6.1.3.1 Verify each [ ] inch primary containment NA Yes NA purge valve is sealed closed except for one purge valve in a penetration flow path while in Condition E of this LCO. SR 3.6.1.3.1 SR 3.6.1.3.2 Verify each 20 inch primary containment 31 days Yes Yes purge valve is closed. SR 3.6.1-.3.2 SR 3.6.1.3.3
- Verify each primary containment isolation 31 days Yes Yes manual valve and blind flange that is located outside primary containment. .. is closed.
Page 16 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.6.1.3.4 SR 3.6.1.3.5 Verify the isolation time of each power In accordance with the Yes (92 day No operated, automatic PCIV, except MSIVs, lnservice Testing Program
- Frequency only -
is within limits. - i.e., does not apply if the Frequency being used is the IST Program) SR 3.6.1.3.5 SR 3.6.1.3.6 Perform leakage rate testing for each 36 months with at least 2 Yes (184 day Yes (36 primary containment purge valve with pairs of valves tested every Frequency only - months with at resilient seals. 18 months i.e., does not least 2 pairs apply if the of valves AND Frequency being tested every used is based on 18 months-In accordance with 10 CFR condition of valve only) 50, Appendix J, Testing open) Program AND Once within 92 days, test all remaining purge valves, if any purge valve fails to meet its acceptance criteria SR 3.6. 1.3.6 SR 3.6.1.3. 7 Verify the isolation time of, each MSIV is ... In accordance with the Yes (18 month . No lnservice Testing Program Frequency only - i.e., d.oes not apply if the Frequency being used is the IST Program) Page 17 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number_ Frequency Number Surveillance) TSTF-425 License Amendment SR 3.6.1.3.7 SR 3.6.1.3.8 Verify each automatic PCIV actuates to 24 months Yes Yes the isolation position ...
NA SR 3.6.1.3.12 Verify each [ ] inch primary containment NA Yes NA purge valve is blocked to restrict the valve from opening > [50]%. SR 3.6.1.4.1 SR 3.6.1.4.1 Verify primary containment to auxiliary 12 hours Yes Yes building differential pressure is within limits. SR 3.6.1.5.1 SR 3.6.1.5.1 Verify primary containment average air 24 hours Yes Yes temperature is within limit. SR 3.6.1.6.1 SR 3.6.1.6.1 Verify each LLS valve relief-mode In accordance with the Yes (18 month No actuator strokes when manually actuated. lnservice Testing Program Frequency on a on a Stagger~d Test Staggered Test Basis ... Basis ... ) SR 3.6.1.6.2 SR 3.6.1.6.2 Verify the LLS System actuates on an 24 months Yes Yes actual or simulated automatic initiation signal. SR 3.6.1.7.1 SR 3.6.1.7.1 Verify each RHR containment spray 31 days Yes Yes subsystem manual ... is in the correct position. Page 18 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-42"5 License Amendment SR 3.6.1.7.3 SR 3.6.1. 7.2 Verify each RHR pump develops a flow In accordance with the Yes (92 day No rate of ... lnservice Frequency only -
Testing Program i.e., does not apply if the Frequency being used is the IST Program) SR 3.6.1. 7.4 SR 3.6.1. 7.3 Verify each RHR containment spray 24 months Yes Yes subsystem automatic valve in the flow path actuates ... SR 3.6.1.7.5 SR 3.6.1. 7.4 Verify each spray nozzle is unobstructed. At first refueling Yes (10 year Yes (10 year Frequency only) Frequency AND only) 10 years NA STS 3.6.1.8, Penetration Valve Leakage Control System (PVLCS), and associated SRs are NA for GGNS SR 3.6.1.9.1 SR 3.6.1.9.1 Operate each outboard MSIV LCS 31 days Yes Yes 1 blower ... SR 3.6.1.9.2 SR 3.6.1.9.2 Deleted not applicable Yes No SR 3.6.1.9.3 SR 3.6.1.9.3 Perform a system functional test of each 24 months Yes Yes MSIV LCS subsystem. Page 19 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in .
GGNSSR GGNS Surveillance Rev. 4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.6.2.1.1 SR 3.6.2.1.1 - Verify suppression pool average
- 24 hours Yes (24 hour Yes (24 hour temperature is within the applicable limits. Frequency only) Frequency AND only) *--
5 minutes when performing testing ... SR 3.6.2.2.1 SR 3.6.2.2.1 Verify suppression pool water level is 24 hours Yes Yes within limits. SR 3.6.2.3.1 SR 3.6.2.3.1 Verify each RHR suppression pool 31 days Yes Yes cooling subsystem manual, power operated, and automatic valve ... is in the correct position or can be aligned to the correct position. SR 3.6.2.3.3 SR 3.6.2.3.2 Verify each RHRpump develops a flow In accordance with the Yes (92 day No rate ... to the suppression pool. lnservice Testing Program Frequency only - i.e., does not apply if the Frequency being used is the IST
- Program)
SR 3.6.2.4.1 SR 3.6.2.4.1 Verify upper containment pool water 24 hours Yes Yes level, .. SR 3.6.2.4.2 SR 3.6.2.4.2 Verify upper containment pool water 24 hours Yes Yes temperature is s 125°F. Page 20 of 35
- Grand Gulf Nuclear Station {GGNS), Unit 1 TS Surveillance Requirements {SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev. 4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.6.2.4.3 SR 3.6.2.4.3 Verify each SPMU sub$ystem manual, 31 days Yes Yes*
power operated, and automatic valve ... is in the correct position. SR 3.6.2.4.4 SR 3.6.2.4.4 Verify all upper containment pool gates 31 days
- Yes Yes are in the stored position or are otherwise removed from the upper containment pool.
SR 3.6.2.4.5 SR 3.6.2.4.5 Verify each SPMU subsystem automatic 24 months Yes Yes valve actuates to the correct position on an actual or simulated automatic initiation _/ signal. GGNS TS 3.6.3.1, Primary Containment Hydrogen Recombiners, and. associated SRs were deleted in license Amendment 166. SR 3.6.3.2.1 SR 3.6.3.1.1 Energize each primary containment and 184 days Yes Yes drywell hydrogen igniter division... SR 3.6.3.2.2 SR 3.6.3.1.2 Energize each primary containment and 92 days Yes Yes drywell hydrogen igniter division ... SR 3.6.3.2.3 SR 3.6.3.1.3 Verlfy each required igniter in 24 months Yes Yes inaccessible areas develops sufficient current draw ... SR 3.6.3.2.4 SR 3.6.3.1.4 Verify each required igniter in accessible 24 months Yes Yes areas develops a surface temperature ... Operate each drywell purge subsystem for~ 15 minutes. Page 21 of 35
. Attachment 7 - Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS SurveiUance Description SR Frequency
- modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number
- Surveillance) TSTF-425 License Amendment SR 3.6.3.3.3 SR 3.6.3.2.2 Verify each drywell purge subsystem flow 24 months Yes Yes.
rate ... NA SR 3.6.4.1.1 [Verify [secondary containment] vacuum NA Yes NA is ~ [0.25] inch of vacuum water gauge.] SR 3.6.4.1.1 SR 3.6.4.1.2 Verify all auxiliary building and enclosure 31 days Yes Yes building equipment hatches are closed ... SR 3.6.4.1.2 SR 3.6.4.1.3 Verify one auxiliary building and 31 days Yes Yes enclosure building access door in each access opening is closed ... SR 3.6.4.1.3 SR 3.6.4.1.4 Verify secondary containment can be 24 months on a Staggered Yes Yes drawn down ... using one stat:1dby gas Test Basis.:. treatment (SGT) subsystem. SR 3.6.4.1.4 SR 3.6k1.5 Verify the secondary containment can be 24 months on a Staggered Yes Yes maintained ... for 1 hour using one SGT Test Basis.:.
- subsystem at a flow rate ...
SR 3.6.4.2.1 SR 3.6.4.2.1 Verify each secondary containment 31 days Yes Yes isolation manual valve, damper, rupture disk, and blind flange ... is closed, SR 3.6.4.2.2 SR 3.6.4.2.2 Verify the isolation time of each power In accordance with the Yes (92 day No operated, automatic SCIV is within limits. - lnservice Testing Program Frequency only - i.e., does not - apply if the Frequency being used is the-lST Program) Page 22 of 35
- Grand Gulf Nuclear Station {GGNS), Unit 1 TS Surveillance Requirements {SRs) to NUREG-1434 SRs Cross-Reference * -
GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Su.rveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.6.4.2.3 SR 3.6.4.2.3 Verify each automatic SCIO actuates to 24 months Yes Yes the isolation position ... SR 3.6.4.3.1 SR 3.6.4.3.1 Operate each SGT subsystem for ... 31 days Yes Yes SR 3.6.4.3.3 SR 3.6.4.3.3 Verify each SGT subsystem actuates ... 24 months Yes Yes NA SR 3.6.4.3.4 [Verify each SGT filter cooling bypass NA Yes NA damper can be opened and the fan started.] Page 23 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS SLJrveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency
.Number Surveillance) TSTF-425 License Amendment SR 3.6.5.1.1 SR 3.6.5.1.1 Verify bypass leakage is less than or 24 months following 2 Yes (18 month Yes (120 (Refer to equal to the bypass leakage limit. consecutive tests with Frequency) month GGNS License bypass leakage greater than Frequency-Amendment However, during the first unit startup the bypass leakage limit. .. Refer to 209 and 214) following bypass leak rate testing ... GGNS AND License Amendments 48 months following a test 209 and 214) with bypass leakage greater than the bypass leakage limit AND
--------------NOTE.-------------
SR 3.0.2 is not applicable for extensions > 12 months. 120 months except that the next drywell-bypass leak rate test performed after the October 19, 2008 test shall be performed no later than the plant restart after the End of Cycle 22 Refueling Outage. SR 3.6.5.1.2 SR 3.6.5.1.2 Visually inspect the exposed accessible Once prior to performance Yes (40 month No interior and exterior surfaces of the of each Type A test required Frequency) drywell. by SR 3.6.1.1.1 Page 24 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment NA SR 3.6.5.2.1 Verify seal leakage rate is ... when the NA Yes NA gap between the door seals is ...
NA SR 3.6.5.2.2 Verify drywell airlock seal air flask NA Yes NA pressure ... SR 3.6.5.2.1 SR 3.6.5.2.3 Verify only one door in the drywell air lock 24 months Yes (18 month Yes can be opened at a time. Frequency) NA SR 3.6.5.2.4 Verify overall drywell air lock leakage rate NA Yes NA is ... by performing an overall air lock leakage test at. .. NA SR 3.6.5.2.5 Verify from an initial pressure of [90] psig, NA Yes NA the drywell airlock seal pneumatic system pressure does not decay ... NA SR 3.6.5.3.1 [Verify each [ ] inch drywell purge NA Yes NA
~-
isolation valve is sealed closed.] SR 3.6.5.3.1 SR 3.6.5.3.2 Verify each 20 inch drywell purge 31 days Yes Yes isolation valve is closed. SR 3.6.5.3.3 SR 3.6.5.3.4 Verify the isolation time of each power In accordance with the Yes (92 day No operated, automatic drywell isolation lnservice Testing Program Frequency only - valve is within limits. i.e., does not apply if the Frequency being _/ used is the IST Program). SR 3.6.5.3.4 SR 3.6.5.3.5 Verify each automatic drywell isolation 24 months Yes Yes valve actuates to the isolation position ... NA SR 3.6.5.3.6 [Verify each [ ] inch drywell purge NA Yes NA isolation valve is blocked to restricUhe valve from opening > [50]%. Page 25 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.6.5.4.1 SR 3.6.5.4.1 Verify drywell-to-primary containment 12 hours Yes Yes differential pressure is within limits.
SR 3.6.5.5.1 SR 3.6.5.5.1 Verify drywall average air temperature is 24 hours Yes Yes
.within limit.
SR 3.6.5.6.1 SR 3.6.5.6.1 Verify each vacuum breaker and its 7 days Yes Yes associated isolation valve is closed. SR 3.6.5.6.2 SR 3.6.5.6.2 Perform a functional test of each vacuum 31 days Yes Yes breaker and its associated isolation valve. SR 3.6.5.6.3 SR 3.6.5.6.3 Verify the opening pressure differential of 24 months Yes Yes each vacuum breaker and isolation valve is s 1.0 psid. Section 3.7, Plant Systems SR 3.7.1.1 SR 3.7.1.1 Verify the water level of each UHS basin 24 hours Yes Yes is ... NA SR 3.7.1.2 [Verify the water level [in each SSW NA Yes NA pump well of the intake structure] is ... ] NA SR 3.7.1.3 [Verify the average water temperature of NA Yes NA [UHS] ... ] SR 3.7.1.2 SR 3.7.1.4 Operate each SSW cooling tower fan 31 days Yes Yes for ... SR 3.7.1.3 SR 3.7.1.5 Verify each required SSW subsystem 31 days Yes Yes manual, power operated, and automatic valve ... is in the correct position. SR 3.7.1.4 SR 3.7.1.6 Verify each SSW subsystem actuates ... 24 months Yes Yes NA SR 3.7.2.1 Verify water level of the [a.standby NA Yes NA service water] cooling tower basin is ... Page 26 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 )
SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev. 4SR . (NUREG-1434 Description if no GGNS modified by Proposed
*Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.7.2.1 SR 3.7.2.2 Verify each required HPCS SWS manual, 31 days Yes Yes power operated, and automatic valve ... is Jn the correct position. "
SR 3.7.2.2 SR 3.7.2.3 Verify the HPCS SWS actuates ... 24 months Yes Yes SR 3.7.3.1 SR 3.7.3.1 Operate each CRFA subsystem for ... 31 days .. Yes Yes SR 3.7.3.3 SR 3.7.3.3 Verify each CRFA subsystem actuates ... 24 months Yes Yes SR 3.7.4.1 SR 3.7.4.1 Verify each control room AC subsystem 24 months Yes Yes has the capability to remove the assumed heat load ... SR 3.7.5.1 SR 3.7.5.1 Verify the gross gamma activity rate of Once within 4 hours after. .. Yes (31 day No the noble gases ... Frequency only) SR 3.7.5.2 . Verify the gross gamma activity rate of 31 days Yes the noble gases ... SR 3.7.6.1 SR 3.7.7.1 Verify the fuel pool water level is ... 7 days Yes Yes SR 3.7.7.1 SR 3.7.6.1 Verify ohe complete cycle of each main 31 days Yes Yes turbine bypass valve. - SR 3.7.7.2 SR 3.7.6.2 Perform a system functional test. 18 months . Yes Yes NA SR 3.7.6.3 Verify the Turbine Bypass System NA Yes NA Response Time ... Section 3.8, Electrical Systems SR 3."8.1.1 SR 3.8.1.1 Verify correct breaker alignment and 7 days Yes Yes indicated power availability ... SR 3.8.1.2. SR 3.8.1.2 Verify each DG starts from standby 31 days Yes Yes conditions and achieves ... Page 27 of 35
- Grand Gulf Nuclear Station (GGNS),_ Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR frequency NUREG.;1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Survemance) TSTF-425 License.
Amendment SR 3.8.1.3 SR 3.8.1.3 Verify each DG operates for ;:: 60 31 days Yes Yes minutes ... SR 3.8.1.4 SR 3.8.1.4 Verify each DG day tank contains ... 31 days Yes Yes SR 3.8.1.5 SR 3.8.1.5 Check for and remove accumulated water 31 days Yes Yes from each day tank. SR 3.8.1.6 SR 3.8.1.6 Verify the fuel oil transfer system 31 days Yes Yes operates to automatically transfer fuel oil... '
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tRijg~!~ t~§~~;g .~1ttii~;iige§Jg11 ~rit~iji~** SR 3.8.1.21 SR 3.8.1.7 Refer to GGNS SR 3.8.1.21 below. SR 3.8.1.8 SR 3.8.1.8 Verify manual transfer of unit power 24 months Yes Yes supply ... SR 3.8.1.9 SR 3.8.1.9 Verify each DG rejects a load greater 24 months Yes Yes than or equal to its associated single largest post accident load ... SR 3.8.1.10 SR 3.8.1.10 Verify each DG does not trip and voltage 24 months Yes Yes is maintained ... SR 3.8.1.11 SR 3.8.1.11 Verify on an actual or simulated loss of 24 months Yes Yes offsite power signal ... SR 3.8.1.12 SR 3.8.1.12 Verify on an actual or simulated 24 months Yes Yes Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and ... _- SR 3.8.1.13 SR 3.8.1.13 Verify each DG's non-critical automatic 24 months Yes Yes trips are bypassed on an actual or simulated ECCS initiation signal. Page 28 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 S~s Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.8.1.14 SR 3.8.1.14 Verify each DG operates for ~ 24 hours ... 24 months Yes Yes SR 3.8.1.15 SR 3.8.1.15 Verify each DG starts and achieves ... 24 months Yes Yes SR 3.8.1.16 SR 3.8.1.16 Verify each DG ... 24 months Yes Yes SR 3.8.1.17 SR 3.8.1.17 Verify, with a DG operating' in test mode 24 months Yes Yes and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by ...
SR 3.8.1.18 SR 3.8.1.18 Verify interval between each sequenced 24 months Yes Yes load block is within +/-10% of design interval for each automatic load sequencer. SR 3.8.1.19 SR 3.8.1.19 Verify, on an actual or simulated loss of 24 months Yes Yes offsite power signal in conjunction with an actual or simulated ECCS initiation signal... SR 3.8.1.20 . SR 3.8.1.20 Verify, when started simultaneously from 10 years Yes Yes standby condition, each DG achieves ... SR 3.8.1.21 SR 3.8.1.7 Verify each DG starts from standby 184 days Yes Yes conditions and achieves ... SR 3.8.3.1 SR 3.8.3.1 Verify each fuel oil storage tank 31 days Yes Yes contains; .. SR 3.8.3.2 SR 3.8.3.2 Verify lube oil inventory is ... 31 days Yes Yes, SR 3.8.3.4 SR 3.8.3.4 Verify each required DG air start receiver 31 days Yes Yes pressure ... SR 3.8.3.5 SR 3.8.3.5. *Check for and remove accumulated water 31 days Yes Yes from each fuel oil storage tank ... Page 29 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Proposed Rev.4SR (NUREG-1434 Description if no GGNS modified by Number* Frequency License Number Surveillance) TSTF-425 Amendment SR 3.8.4.1 SR 3.8.4.1 Verify battery terminal voltage is ... on 7 days Yes Yes float charge.
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- SR 3.8.4.6 SR 3.8.4.2 Verify each Division 1 and 2 required 24 months Yes Yes battery charger supplies ... amps ...
SR 3.8.4.7 SR 3.8.4.3 Verify battery capacity is adequate to 24 months Yes Yes supply, and maintain in Operable status, the required emergency loads ... Page 30 of 35
- Grand Gulf Nuclear Station {GGNS}, Unit 1 TS Surveillance Requirements {SRs} to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Proposed Rev.4SR (NUREG-1434 Description if no GGNS modified by Number Frequency License Number Surveillance) TSTF-425 Amendment SR 3.8.4.8 SR 3.8.6.6 Verify battery capacity is~ 80% ... when 60 months Yes (60 month Yes (60 (Moved to STS subjected to a performance discharge Frequency only - month
.3.8.6 per TSTF- test. AND STS SR 3.8.6.6) Frequency 360) only) 18 months (Note: ... when battery shows degradation or has reached 85% of expected life.)
NA SR 3.8.6.1 Verify each battery float current is 5 [2] NA Yes NA (Added by TSTF- amps. 360) SR 3.8.6.1 SR 3.8.6.2 - pilot Verify battery cell parameters meet Table 7 days Yes (31 day Yes (Deleted by cell voltage 3.8.6-1 Category A limits (i.e., pilot cell) .. Frequency for TSTF-360) STS SR 3.8.6.2) SR 3.8.6.2 SR 3.8.6.3- Verify battery cell parameters meet Table 92 days Yes (31 days for Yes (92 days (Deleted by electrolyte level 3.8.6-1 Category B limits (i.e., connected STS SR 3.8.6.3 only) TSTF-360) SR 3.8.6.5 - float cells). AND and 92 days for voltage STS SR 3.8.6.5) Once within 72 hours after ... SR 3.8.6.3 SR 3.8.6.4 Verify average electrolyte temperature of 92 days Yes (31 day Yes representative cells is ... Frequency) NA STS 3.8.7, Inverters - Operating, and associated SRs are NA for GGNS NA STS 3.8.8, Inverters - Shutdown, and associated SRs are NA for GGNS SR 3.8.7.1 SR 3.8.9.1 Verify correct breaker alignments and 7 days Yes Yes voltage to required AC and DC electrical power distribution subsystems. Page 31 of 35
./' - Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.8.8.1 SR 3.8.10.1 Verify correct br_eaker alignments and 7 days Yes Yes voltage to required AC ancf DC electrical power distribution subsystems.
Section 3.9, Refueling Operations SR 3.9.1.1 SR 3.9.1.1 Perform Channel Functional Test on each 7 days Yes Yes of the following required refueling equipment interlock inputs ... SR3.9.2.1 SR 3.9.2.1 Verify reactor mode switch locked in 12 hours Yes Yes refuel position. SR 3.9.2.2 SR 3.9.2.2 Perform Channel Functional Test. 7 days Yes Yes SR 3.9.3.1 SR 3.9.3.1 Verify all control rods are fully inserted. 12~hours Yes Yes SR 3.9.5.1 SR 3.9.5.1 Insert each withdrawn control rod at least 7 days Yes Yes one notch. SR 3.9.5.2 SR 3.9.5.2 Verify each withdrawn control rod scram 7 days Yes Yes accumulator pressure ... SR 3.9.6.1 SR 3.9;6.1 Verify RPV water level. .. 24 hours Yes Yes SR 3.9.7.1 SR 3.9.7.1 Verify RPV water level ... 24 hours Yes Yes SR 3.9.8.1 SR 3.9.8.1 Verify one decay heat removal subsystem 12 hours Yes Yes is operating. Verify one decay heat removal subsystem is operating. Page 32 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Proposed Rev.4SR (NUREG-1434 Description if no GGNS modified by Number Frequency License Number Surveillance) TSTF-425 Amendment Section 3.10, Special Operations SR 3.10.2.1 SR 3.10.2.1 Verify all control rods are fully inserted in 12 hours Yes Yes core cells ...
SR 3.10.2.2 SR 3.10.2.2 Verify no Core Alterations are in progress. 24 hours Yes Yes SR 3.10.3.2 SR 3.10.3.2 Verify all control rods ... are disarmed. 24 hours Yes Yes SR 3.10.3.3 SR 3.10.3.3 Verify all control rods ... are fully inserted. 24 hours Yes Yes SR 3.10.4.2 SR 3.10.4.2 Veri~y all control rods ... are disarmed. 24 hours Yes Yes SR 3.10.4.3 SR 3.10.4.3 Verify all control rods ... are fully inserted. 24 hours Yes Yes I SR 3.10.4.4 SR 3.10.4.4 Verify a control rod withdrawal block is 24 hours Yes Yes inserted. SR 3.10.5.1 SR 3.10.5.1 Verify all control rods ... are fµlly inserted. 24 hours Yes Yes SR 3.10.5.2 SR 3.10.5.2 Verify all control rods ... are disarmed. 24 hours Yes Yes SR 3.10.5.3 SR 3.10.5.3 Verify a control rod withdrawal block is 24 hours Yes Yes inserted. SR 3.10.5.5 SR 3.10.5.5 Verify no Core Alterations are in progress. 24 hours Yes Yes SR 3.10.6.1 SR 3.10.6.1 Verify the four fuel assemblies are 24 hours Yes Yes removed ... SR 3.10.6.2 SR 3.10.6.2 Verify all other control rods ... are fully 24 hours Yes Yes inserted. Page 33 of 35
- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency modified in GGNSSR GGNS Surveillance Rev.4SR (NUREG-1434 Description if no GGNS modified by Proposed Number Frequency Number Surveillance) TSTF-425 License Amendment SR 3.10.6.3 SR 3.10.6.3 Verify fuel assemblies being loaded are in 24 hours Yes Yes compliance with an approved spiral reload sequence.
SR 3.10.8.4 SR 3.10.8.4 Verify no other Core Alterations are in 12 hours Yes Yes progress. SR 3.10.8.6 SR 3.10.8.6 Verify CRD charging water header 7 days Yes Yes pressure ...
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- Grand Gulf Nuclear Station (GGNS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference GNR0-2018/00013 SR Frequency NUREG-1434 GGNS Surveillance Description SR Frequency
- modified in GGNSSR GGNS Surveillance Proposed Rev.4SR (NUREG-1434 Description if no GGNS modified by Number Frequency License Number Surveillance) TSTF-425 Amendment Page 35 of 35}}