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Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 4 of 6
	ML16071A152
Person / Time
Site:	Hatch, Vogtle, Farley
Issue date:	03/03/2016
From:	; Southern Nuclear Operating Co
To:	; Office of Nuclear Reactor Regulation
Shared Package
ML16071A108	List: ML16071A110; ML16071A126; ML16071A132; ML16071A136; ML16071A137; ML16071A140; ML16071A144; ML16071A146; ML16071A147; ML16071A149; ML16071A150; ML16071A152; ML16071A153; ML16071A158; ML16071A160; ML16071A166; ML16071A170; ML16071A174; ML16071A176; ML16071A180; ML16071A181; ML16071A184; ML16071A185; ML16071A187; ML16071A188; ML16071A193; ML16071A195; ML16071A198; NL-15-1898, Enclosure 2: EAL Deviations and Differences Maxtrix (Farley, Hatch, and Vogtle) Part 1 of 4; NL-15-1898, Enclosure 2: EAL Deviations and Differences Maxtrix (Farley, Hatch, and Vogtle) Part 2 of 4; NL-15-1898, Enclosure 2: EAL Deviations and Differences Maxtrix (Farley, Hatch, and Vogtle) Part 3 of 4; NL-15-1898, Enclosure 2: EAL Deviations and Differences Maxtrix (Farley, Hatch, and Vogtle) Part 4 of 4; NL-15-1898, Enclosure 3: Hatch EAL Calculations - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 1 of 3; NL-15-1898, Enclosure 3: Hatch EAL Calculations - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 2 of 3; NL-15-1898, Enclosure 3: Hatch EAL Calculations - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 3 of 3; NL-15-1898, Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 1 of 6; NL-15-1898, Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 2 of 6; NL-15-1898, Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 3 of 6; NL-15-1898, Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 4 of 6; NL-15-1898, Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 5 of 6; NL-15-1898, Enclosure 4: EAL Verification and Validation Documents - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 6 of 6; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 1 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 2 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 3 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 4 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 5 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 6 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 7 of 8; NL-15-1898, Enclosure 5: Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 8 of 8; NL-15-1898, Enclosure 5: Vogtle Marked-Up EAL Schemes - License Amendment Request for Changes to EAL Schemes to Adopt NEI 99-01 Rev. 6 and to Modify Radiation Monitors at Farley Nuclear Plant. Part 1 of 4; ... further results
References
	NL-15-1898
	Download: ML16071A152 (48)
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V1 8Page 1 of 10SOUTHERN NUCLEARIPLANT El. HATCHPAGE 9 OF 30DOUMNTTILE t DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL t 34AB-T22-003-1 5.14ATTACHMENT 2 ATT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1G31-R604) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1H11-P614, 1G31-R604 Value Value0F o158' ELEVATION AREA (RWCU)101 B Pump Room (1G31-N016D) 150 212.5102 B Pump Room DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Room (1G31-N016B) 150 212.5104 Hx Room DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B (1E11-N009B) 150 212.5108 RHR/CS B DIFF(1E11-N030B/1E11-N029B) 40 98HPCl ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245110 HPCI VENT AIR DIFF (1E41-N029B/1E41-N028B) NA NA(not used)RCIC ROOM AREA111 Emer Area CIr (1 E5I-N023B) 167.5 310112 RCIC VENT AIR DIFF (1E51-N022B/1E51-N021 B) NA NA(not used)TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1E51-N025D) 167.5 212.5115 VENT AIR DIFF (1E51-N027B/1E51-N026B) 42 102116 VENT AIR DIFF (1 E51-N027D/1 E51-N026D) 42 102HPCI PIPE PENETRATION ROOM117 1E41-N046B 150 212.5Posted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 2 of 10PAGE 10 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 3 ATTACH. PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1 G31 -R608) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1IH11-P614, 1G31-R608 Value ValueoF o158' ELEVATION AREA (RWGU)101 A Pump Room (1G31-N016C) 150 212.5102 A Pump Room DIFF (1G31-N022B/1G31-N023B) 67 98103 Hx Room (1G31-N016E) 150 212.5104 Hx Room DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF (1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A (lE1 1-N009A) 150 212.5108 RHRICS A DIFF (1EI11-N030A/1 E11-N029A) 40 98HPCI ROOM AREA109 Pump Room (1E41-N024) 167.5 245110 Emer Area CIr (1 E41 -N030A) 167.5 245111 HPCl VENT AIR DIFF (1 E41-N029A/11E41-N028A) NA NA(not used)_________RClC ROOM AREA112 Pump Room (1E51-N011) 167.5 310113 Emer Area CIr (1E51-N023A) 167.5 310114 RCIC VENT AIR DIFF (1 E51-N022A/1 E51-N021A) NA NA(not used)TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-N025C) 167.5 212.5117 VENT AIR DIFF (1 E51-NO26AI1 E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1 E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm TnI 1B21-N014 192.5 300120 1B21-N016AN0O16B DIFF 60 150HPCI PIPE PENETRATION ROOM 150 212.5121 1E41-N046APosted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 3 of 10PAGE 27 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE ]DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2Max MaxSECONDARY CONTAINMENT TEMPNoml Sfon IHI1-P614, 1G31-R604 0158' ELEVATION AREA (RWCU)101 B Pump Rm (1G31-N016D) 150 212.5102 B Pump Rm DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Rm (1G31-N016B) 150 212.5104 Hx Rm DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B(1E11-N009B) 150 212.5108 RHR/CS B DIFF (1E11-N030B/1E11-N029B) 40 98HPCI ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245RCIC ROOM AREA111 Emer Area Clr (1 E51-N023B) 167.5 310TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1 E51-N025D) 167.5 212.5115 Vent Air DIFF (1E51-N027B/1E51-N026B) 42 102116 Vent Air DIFF (1E51-N027D/1E51-N026D) 42 102HPCl PIPE PENETRATION ROOM117 1E41-N046B 150 212.5RDG RDG1 23Reference 34AB-T22-003- 1MGR-0009 Rev 5.0 Vi18Page 4 of 10PAGE 28 OF 30SOUTHERN NUCLEARIPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT -9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP Max Maxon 1H11-P614, 1G31-R608 Normal Safe158' ELEVATION AREA (RWCU)101 A Pump Rm (1G31-N016C) 150 212102 A Pump Rm DIFF (1G31-N022BI1E51-N023B) 67 98103 Hx Rm (1G31-N016E) 150 212.5104 Hx Rm DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF(1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A(1E11-N009A) 150 212.5108 RHR/CS A DIFF (1E11-N030A/1E11-N029A) 40 98HPCl ROOM AREA109 Pump Rm (1E41-N024) 167.5 245110 EmerArea Clr(1E41-N030A) 167.5 245RCIC ROOM AREA112 Pump Rm (1E51-N011) 167.5 310113 EmerArea CIr (1E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-NO25C) 167.5 212.5117 VENT AIR DIFF (1E51-N026A11E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm Tnl (1B21-N014) 192.5 300120 1B21-N016A/N016B DIFF 60 150HPCI PIPE PENETRATION ROOM121 1E41-N046A 150 212.5I/RDG RDG RDG1 2 3I________Iec 4B-2-0-MGR-0009 Rev 5.0 V18Page 5 of 10PAGE 29 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL 34AB-T22-003-1 5.14ATTACHMENT 10 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT PARAMETERS 1 OF 1Imax 14" aow8rTelw.Ir Irt' 3TabowSTe~ev.t#' aovSe lteev.DIAGONALAREA150212.5I.IV ROOMAIEA wI' h svIo"fl vi" IT 71e,CO4hNMENREFA RADIATIONIMONITORS I [g~11.SS 1211UV~jteVaeIEREL FLO(F AREA1Reathe.J iee (1D21-KG00A) 50 10002 a u(IO141-01 B) 50 10(003 P.uuI o(1O21-K60lD) 50 10004 Dr~weIl 50 10005 SpeltFtmlPool&New~uelStcrage(1D21.K501M 50 10005RB20Wor~ru(1D21K0 X) 50 7 SpentFuel PoC DeuinvEquip{1O21.01C) 150 I1Q000eFu.PocDsrmin, Pmn(1D21.K17) 50 10 ___9 R81irWokArea(1D214K601K) 50 1 00010 RxbSarjiRzdkue (ID214K601L) 50 1 000)11 50 IOQ0012 NothCRVHCU(1021-IQD1P) 50 I100014 R8130N.E~odinku(1D21.K601G) 50 I100015 50 ]1000 __ELEVATION SOUTH AREA16 50 100017 SoutthCAOHCJ(1D2FH(0tN) 50 1000 _18 RCCEEupSWDmgna(1O21.KO1V) 50 I1000NORfN"TI~LAOA AREA19 CR)PumpiWOIagvnI(1D21.(801W) 50 I1000NOfES G4LAREA20 CS&RJIRN~.Edg(1D21-KIE01Y) 50 1000SOUT~fJST ENA-(NAL ARE --_ -21 CS&Rk-IlS,,EDigoza{IDT2.K6O1R) 50 1 (000!J7 ELEVATION AREA ET22 HFOTuwtmieAlui1D214t01T) 150 I10(001OP114S-~1933~I l=l 1I34AB-T22-O03-1OPS-1 933MGR-0009 Rev 5.0 V1 8Page 6 of 10PAGE 9 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 2 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 1(2G31-R604)_________MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H11-P614, OPERATING OPERATING2G31-R604 VALUE VALUE°F °F158' ELEVATION AREA (RWCU)101. B pump room (2G31-N016B) 150 215102. B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103. Hx Room (2G31-N016D) 150 215104. Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105. Valve Nest (2G31-N016F) 150 215106. Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 99SOUTHEAST DIAGONAL AREA107. RHR/CS B (2E11-N009B) 150 190108. RHR/CS B DIFF (2E11-N030B/2E11-N029B) 40 74HPCI ROOM AREA109. Emer area clr (2E41-N030B) 167.5 245110. HPCl vent air DIFF (2E41-N029B/2E41-N028B) NA NA(not used)______ ____RClC ROOM AREA111. Emer Area CIr (2E51-N023B) 167.5 310112. RCIC vent air DIFF (2E51-N022B/2E51-N021B) NA NA(not used)______ ____TORUS ROOM AREA113. Northwest Wall (2E51-N025B) 167.5 212.5114. Southeast Wall (2E51-N025D) 167.5 212.5115. Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116. Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117. 2E41-N046B 167.5 212.5 Vi18Page 7 of 10PAGE 10 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 3 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (2G31 -R608) 1 OF 1MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H1 1-P614, OPERATING OPERATING2G31-R608 VALUE VALUE°F °F158' ELEVATION AREA (RWCU)101. A Pump Room (2G31-N016A) 150 215102. A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 99103. Hx Room (2G31-N016C) 150 215104. Hx Room DIFF (2G31-N023C/2G31-N022C) 67 99105. Phase Sep Rm (2G31-N016E) 150 215106. Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 99NORTHEAST DIAGONAL AREA107. RHR/CS A (2E1 1-N009A) 150 215108. RHR/CS A DIFF (2E11-N030AN2E11-N029A) 40 74HPCI ROOM AREA109. Pump Rm (2E41-N024) 167.5 245110. Emer Area CIr (2E41-N03OA) 167.5 245111. HPCI Vent Air DIFF (2E41-N029A/2E41-N028A) NA NA(not used)__________RCIC ROOM AREA112. Pump Rm (2E51-N011) 167.5 310113. Emer Area CIr (2E51-N023A) 167.5 310114. RCIC Vent Air DIFF (2E51-N022A12E51-N021A) NA NA(not used)TORUS ROOM AREA115. West Wall (2E51-N025A) 167.5 212.5116. Northeast Wall (2E51-N025C) 167.5 212.5117. Torus Vent Air DIFF (2E51-N027A/2E51-N026A) 42 98118. Torus Vent Air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119. Main Steam Tunnel (2B21-N014) 192.5 310120. Main Stm Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150HPCI PIPE PENETRATION ROOM121. 2E41 -N046A 167.5 212.5 V18Page 8 of 10PAGE 30 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT _9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2SECONDARY CONTAINMENT TEMPMMAon 2H11-P614, 2G31-R604 NORMALj SAFE158' ELEVATION AREA (RWCU)101 B pump room (2G31-N016B) 150 215102 B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103 Hx Room (2G31-NO16D) 150 215104 Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105 Valve Nest (2G31-N016F) 150 215106 Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 9SOUTHEAST DIAGONAL AREA107 RHR/CS B (2E11-N009B) 150 J190108 RHR/CS B DIFF (2E1 1-N030B/2G31-N029B) 40 J 74HPCI ROOM AREA109 Emer Area CIr (2E41-N030B) I67.5 245RCIC ROOM AREA111 Emer Area CIr (2E51-N023B) 16. 1TORUS ROOM AREA113 Northwest Wall (2E51-N025B) 167.5 212.5114 Southeast Wall (2E51-N025D) 167.5 212.5115 Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116 Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117 2E41-N046B Ii7.5I 212.5Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 SOUTHERN NUCLEARPLANT E.I. HATCHVi18Page 9 of 10PAGE 31 OF 37DOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP MAX MAXon 2H11-P614, 2G31-R608 NORMAL[ SAFE158' ELEVATION AREA (RWCU)101 A Pump Room (2G31-N016A) 150 21102 A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 9103 Hx Room (2G31-N016C) 150 21104 Hx Room DIFF (2G31-N023C/2G31-N022C) 67 9105 Phase Sep Rm (2G31-N016E) 150 21106 Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 9NORTHEAST DIAGONAL AREA107 RHR/CS A (2E1 1-N009A) 150 21108 RHR/CS A DIFF (2E11-N030AI2E11-N029A) 40 174HPCl ROOM AREA109 Pump Rm (2E41-N024) 167.5 245110 Emer Area Clr(2E41-N030A) 167.5/ 245RClC ROOM AREA112_Pump Rm_(2E51-N011) 167.5 _310113 Emer Area Clr (2E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (2E51-N025A) 167.5 212.5116 Northeast Wall (2E51-N025C) 167.5 212.5117 Torus vent air DIFF (2E51-N027A12E51-N026A) 42 98118 Torus vent air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119 Main Steam Tunnel (2B21-N014) 192.5 310120 Main Steam Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150RDG RDG1 RDG1 2 3-B_HPCl PIPE PENETRATION ROOMI121 2E41,N046A [167.5 212.5_Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 V1 8Page 1 0 of 10PAGE 35 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 1"1 ATTACHMENT PAGE:TITLE: SECONDARY CONTAI NMENT PARAMETERS 1 OF 1Table 4 o'9tA~hG~iWAfliI I C0NbleN 5 A101102AREA WATER LEVELSMax NanulMaxSafe.___ 4" r/5T'sia 33 isv .1.AREA4"iow ST ealeion!$"o8T 1ev'.4icvelTelwian 27.bovel7'elw.diov.STal.vglwit#' above $'t' 4" isve 8'uleiion14" isy rr sh,4 aov 57' ekydontt" above 37' .ev.Table 6 ARIA MOR10.3yaw awS UUHd113 l 51-N058) I167.5 212.5114 Sou WlbeI (2E514NU50) l167.5 212.5116 ToqusM VtOIFF 42 901 A Pw~own%2;G31.#408Ao mpRoooN2G314 t3Phu Sep Rm(2m1.N01E)Va15067'so57150RiVa21599215982151 Reac had (2D21-K601A) 50 1Q0003 SfouIlo&NswFu l~g.(2f21.KBO1M) 50 10004 ahFboor(2D214(SI11K) 5o 10o0G Reeor Vesse!RFloor (2Q21.K811 L) 50 1Q00063 (2D214,SO1T) 50 10]007 HV o¢W 50 1008 Spn u olPsaea 50 10009 RB 18 qelegIoor(2O21..KO0R) 50 100010 R81W Samispuue t.lme(221.(8O1S) 50 1Q000I'I R818 cou~rol pa-.(2O21-K601U) 15O t000__13 S reaIW (2D21.(501D) 50 1000__15Dean um eupmntronara 50 1000__`10001307 ELEVATION ARE.A (NSRUThWSN(R11PMB(2T2IMOIF) L AO RtOA217 50 .100022 RC1S.W4~odgAii(2D21,,K601X) 50 .100023 cs&rRls~dagoi(2V214WO1Y) 150 1000O115 16+7.5 21 21542 198l34AB-.T22-003-2OPS-1932OPS-1 932 V19Page 1 of 4PAGE 2 OF 3SOUTHERN NUCLEARPLANT E.I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:ARP'S FOR CONTROL PANEL 2H1 1-P657, 34AR-657-901-2 I 23.1ALARM PANEL 1UNIT 22H11-P657 -1 (LEFT)657-001 657-002 657-00.3 557-004 57-005 657-006 657-007 657-008 657-009657-019 657-020 657-021 57-02 657-023 657-024 657-025 657-026 657-027657-037 657 -03 6 57-03;;57-040 6 7-041 657-042 657-043 657-044 657-045657-055 657-05S G57 057 657-058 -5705 657-060 657-061 657-062 657-063657-07 657-074 657-075 657-0Th 657-77 657-07 657-079 657-080 657-081657-091 57 0 2 657-093 557-094 657-095 657 096 65-097 657-098 657-0992H11-P657 -1 (RIGHT)657-010 657-011 G57-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 ss57-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 65 7-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-0B3 65-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108Level Of Use ARPsCONTINUOUS ALLREFERENCE NoneINFO None Vi19Page 2 of 41.0 IDENTIFICATION:ALARM PANEL 657__ _______SEISMIC* INSTRUMENTATIONTRIGGEREDDEVICE: SETPOINT:2L51-N022 0.08 g horizontal, 0.54 g vertical2L51 -N024 0.18 g horizontal, 0.063 vertical2.0 CONDITION: 3.0 CLASSIFICATION:[ EQUIPMENT STATUSMotion has been detected in Unit 2 Reactor Building on4.LOAINelevation 87' or 185' 4 H0 LOCATION5.0 OPERATOR ACTIONS:5.1 At Panel 1 Hi11-P701, check for further indications of a seismic eventby monitoring Peak Shock Annunciator, 1 L51-R620,for 12.7 Hz amber lights (> 0.08g, OBEY) and 12.7 Hz red lights (> 0.15g, DBE). LII5.2 Refer to Seismic Instrumentation Earthquake Response Manual, SX-18271,for guidance in analyzing seismic data. LI5.3 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. LI5.4 Enter NMP-EP-1 10, Emergency Classification Determination and Initial Action. LI5.5 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. LI6.0 CAUSES:Seismic event

7.0 REFERENCES

8.0 TECH. SPECS./TRMIODCMIFHA:7.1 H-16319, Seismic Measurement Equip Control TRM T3.3.6 Seismic MonitoringPanel & Instrumentation. Instrumentation7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-048-2VER 4.1MGR-0048 Ver. 5.0 Vi19Page 3 of 4UNIT 1IH11-P657 -1 (RIGHT)657-010 657-011 657-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 657-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 657-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-083 657-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108RECORDSThere are no records generated by the procedureCOMMITMENTSNONEMGR-0001 Ver. 4 V19Page 4 of 41.0 IDENTIFICATION:ALARM PANEL 657________SEISMIC PEAKSHCKRECORDERJDEVICE: SETPOINT:1 L51-Vbc-R620 Not available5.0 OPERATOR ACTIONS:5.1 At Panel 1~ H1-P701, check for further indications of a seismic event,by monitoring 1L51-Vbc-R620, Peak Shock Annunciators,for 12.7 Hz amber lights (> 0.08g, OBE) AND 12.7 Hz red lights (_? 0.15g, DBE). El5.2 IF no other indications of a seismic event are present, check the following:* Peak Shock Annunciator, 1L51-vbc-R602, plugged in on Panel 1H1 1-P701 El* BRKR 3 on 120/208V Essential AC Cab, 1R25-S065 El5.3 Refer to SX-18271, Seismic Instrumentation Earthquake Response Manual,for guidance in analyzing seismic data. El5.4 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. El5.5 Enter 73EI-EIP-001-0, Emergency Classifications and Initial Actions. El5.6 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. El6.0 CAUSES:6.1 Seismic event6.2 Power failure

7.0 REFERENCES

8.0 TECH. SPEC.ILCO:7.1 H-16319, Seismic Measurement Equipment Control Unit 2, TRM T3.3.6 Seismic MonitorsPanel and Instrumentation.7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-066-1IVer. 3.0MGR-0048 Ver. 5AG-MGR-75-1101 V20Page 1 of 20SOUTERN UCLAR DCUMNT TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 118DOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-1 13.1EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 8-1 1-14 DATE:N/A SSM /PM N/A DATE N/A 9-11-141.0 CONDITIONSA fire exists at Plant E. I. Hatch. This procedure provides information AND actions necessary tomitigate the consequences of fires AND to maintain an operable shutdown train following firedamage to specific areas.TABLE OF CONTENTSSection Paae2.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.4 112 FT. ELEVATION ......................................................................... 75.5 OIL STORAGE TANK ROOM ............................................................... 75.6 STATION BATTERY ROOMS ............................................................... 85.7 RPS BATTERY ROOMS..................................................................... 85.8 130 FT ELEV. PASSAGEWAYS, HVAC ROOM, HP AREA, RADWASTE LAB ......... 85.9 RPS MG SET ROOM ........................................................................ 85.10 OIL CONDITIONER ROOM ................................................................. 95.11 DC SWITCHGEAR ROOMS................................................................. 95.12 600V SWITCHGEAR ROOM iC ............................................................ 95.13 600V SWITCHGEAR ROOM 1D........................................................... 105.14 TRANSFORMER lCD ROOM ............................................................. 105.15 MAIN CONTROL ROOM, CABLE SPREADING ROOM OR COMPUTER ROOM ....115.16 CONTROL ROOM ROOF .................................................................. 135.4 112 FT. ELEVATION........................................................................ 146.0 DIESEL GENERATOR BUILDING ............................................................. 156.2 DG BATTERY ROOMS..................................................................... 156.3 DG DAY TANK ROOMS.................................................................... 166.4 DG ENGINE ROOMS ...................................................................... 176.5 DG 1A SWGR ROOM 1E (1R22-S005).................................................... 186.6 DG lB SWGR ROOM iF (1R22-S006).................................................... 196.7 DG 1C SWGR ROOM 1G (1R22-S007)................................................... 207.0 YARD ............................................................................................. 217.2 COOLING TOWER ......................................................................... 227.3 INTAKE STRUCTURE...................................................................... 227.4 CONDENSATE STORAGE TANK AREA ................................................. 227.5 NITROGEN STORAGE TANK AREA...................................................... 23 SOUTHERN NUCLEARPLANT E. I. HATCHIV20Page 2 of 20PAGE2 OF 118DOCMEN TTLE IDOCUMENT NUMBER: IVERS ION NO:FI RE PROCEDURE 34AB-X43-001-.1 j 13.17.6 MAIN OR UNIT AUXILIARY TRANSFORMER............................................ 237.7 STARTUP AUXILIARY TRANSFORMER................................................. 237.8 AUXILIARY BOILER........................................................................ 237.9 COOLING TOWER SWITCHGEAR HOUSE.............................................. 237.10 WASTE GAS TREATMENT BUILDING................................................... 237.11 FIRE PUMP HOUSE........................................................................ 237.12 CONDENSATE DEMINERALIZER BUILDING (MUD HOUSE).......................... 237.13 CHLORINE BUILDING...................................................................... 247.14 SECURITY CAS BUILDING................................................................ 247.15 CIRCULATING WATER PUMP PIT ....................................................... 247.16 RECOMBINER BUILDING ................................................................. 247.17 TSC247.18 HIGH VOLTAGE SWITCHYARD .......................................................... 247.19 DISCHARGE STRUCTURE................................................................ 247.20 MAIN STACK................................................................................ 247.21 DEEPWELL PUMP HOUSE................................................................ 247.22 HYDROGEN/OXYGEN BULK STORAGE FACILITY..................................... 247.23 HYDROGEN/OXYGEN SUPPLY INTERMEDIATE VALVE STATION.................. 257.24 HYDROGEN/OXYGEN TURBINE BLDG ISOLATION VALVE STATION............... 257.25 HP/CHEMISTRY FILTER TRAIN (NORTH SIDE OF SECURITY CAS BLDG)......... 267.26 ISFSI / DRY STORAGE AREA (SOUTH OF PROTECTED AREA) ..................... 268.0 UNIT 1 REACTOR BUILDING.................................................................. 278.3.3 Torus Room, South Half............................................................... 278.3.4 RClC Room ............................................................................ 288.3.5 Div I RHR and Core Spray Corner Room ............................................ 288.4.3 Torus Room, North Half ............................................................... 298.4.4 CRD Room............................................................................. 308.4.5 Div II RHR and Core Spray Corner Room............................................ 318.4.6 HPCl Room............................................................................. 318.4.7 130 Ft Elevation, North Half........................................................... 328.4.8 158 Ft Elevation, North Half........................................................... 338.4.9 164 Ft HVAC and SBGT Room ....................................................... 348.4.10 Fuel Pool Cooling and Heat Exchanger Room....................................... 378.4.11 RWCU Equipment Room.............................................................. 378.4.12 203 Ft................................................................................... 388.5 REClRCULATION PUMP / ASD AREA MG SET ROOM ................................ 388.6 DRYWELL................................................................................... 399.0 TURBINE BUILDING ........................................................................... 409.2 TURBINE BUILDING OR WEST CABLEWAY............................................ 409.3 EAST CABLEWAY.......................................................................... 419.4 EAST CABLEWAY FOYER ................................................................ 4110.0 RADWASTE BUILDING ........................................................................ 4211.0 RECORDS....................................................................................... 4312.0COMMITMENTS ................................................................................ 43 V20Page 3 of 20SNC PANT .I.HATC I I Pg 85 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 1 OF 5*The Safe Shutdown Paths listed below indicate the Safe Shutdown Train that has been protectedfor a fire in the associated area. The Safe Shutdown path (1 OR 2) least impacted by the fire ineach area was identified AN..._D protected. It is assumed that only one path is available for shutdownfor the purpose of engineering analysis. This does NOT prevent operator use of systems outside ofthe protected path, IF they continue to function as required. For fire areas where protection of onepath cannot be achieved, such as the Main Control Room, Cable Spreading Room, AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND protected from the fire area.* Where circuit failures to protected path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are protected WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 3 (Path 1), Attachment 4 (Path 2), AN Attachment 5 (Path 3 OR RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, although NO_._I specifically protected OR analyzed, may survivethe fire. Circuit faults to unanalyzed equipment have NOT been evaluated.

V20Page 4 of 20SNC LAN E.I. HTCHI IPg 86 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDUREI 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -UI 2 OF 5PREFIRE PLANDWG #CONTROL BUILDING112 FT. ELEV PASSAGEWAYS ORSERVICE AIR COMPRESSOR ROOMOIL RESERVOIR ROOMFREIGHT ELEVATOR OR STAIRWAYAC INVERTER ROOMSTATION BATTERY ROOM 1ASTATION BATTERY ROOM 1 BRPS BATTERY ROOM 1ARPS BATTERY ROOM lBWATER ANALYSIS ROOM ORHOT INSTRUMENT SHOPUNIT 1 130 FT ELEV PASSAGEWAYSHVAC ROOM -130 FT ELEVRPS MG ROOMVERTICAL CABLE CHASEANNUNCIATOR ROOMOIL CONDITIONER ROOMDC SWGR ROOM 1ADC SWGR ROOM lBHEALTH PHYSICS AREA ORRADWASTE LAB600V SWGR ROOM 1C600V SWGR ROOM 1DTRANSFORMERS ROOM lCDCO2 STORAGE TANK AREAMAIN CONTROL ROOMCABLE SPREADING ROOMCOMPUTER ROOMA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43 965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965SHT #5A, B10A,B6A, B13A,B11A,B12A,B15A, B1 4A, B8A, B24A,B25A, B26A,B26A,B27A,B33A, B30A, B32A,B23A, B28A,B29A,B31A,B46A, B48A,B44A,B45A, BPROTECTEDSAFE SHUTDOWNPATH21 and 221211 and 21 and 212212222122122REMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMS2CONTROL ROOM ROOFA4365A,A-43965 50A, B V20Page 5 of 20SNC LANTE. I HATH IPg 87 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE1 34AB-X43-001-1 13.1ATTACHMENT 2 Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 3 OF 5DIESEL GENERATOR BUILDINGDG BUILDING HALLWAYDG 1A BATTERY ROOMDG 1 B BATTERY ROOMDG lC BATTERY ROOMDG 1A DAY TANK ROOMDG 1 B DAY TANK ROOMDG 1 C DAY TANK ROOMDG 1A ENGINE ROOMDG lB ENGINE ROOMDG 1C ENGINE ROOMDG 1A SWGR ROOMDG 1B SWGR ROOMLDG lC SWGR ROOMPREFIRE PLANDWG #A-43966A-43966A-43966A-43 966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SHT #5A, B15A,B11A,B7A,B1 4A, B10A, B6A, B16A, B12A, B8A,B1 7A, B13A, B9A, B1 and 221 and 2121 and 21221221PROTECTEDSAFE SHUTDOWNPATHYARDCOOLING TOWERSINTAKE STRUCTUREPLANT SERVICE WATER VALVE PIT 2APLANT SERVICE WATER VALVE PIT 2BCONDENSATE STORAGE TANK AREANITROGEN STORAGE TANK AREATRANSFORMERSAUXILIARY BOILERCIRC WATER PUMP PITFIRE PROTECTION PUMP HOUSE,WEST AREAA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396674A, B thru 76C,D27A, B50A, B51A,B43A,B41 A, B56A, B61A,B52A,B46A,B1 and 21 and 221111 and 2NA21 and 2 V20Page 6 of 20SNC LANTE. I HATH IPg 88 of 118DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-00 1-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 4 OF 5REACTOR BUILDINGPREFIRE PLANDWG #PROTECTEDSAFE SHUTDOWNPATHSHT #51A,BDIV I RHR AND CORE SPRAY SECORNER ROOMDIV II RHR AND CORE SPRAY NECORNER ROOMCRD CORNER ROOMRCIC ROOMHPCI ROOMTORUS ROOM -SOUTH HALFTORUS ROOM -NORTH HALF130 FT ELEV -SOUTH130 FT ELEV -NORTHREClRC ASD ROOM 1ARECIRC ASD ROOM lBRWCU PUMP A ROOMRWCU PUMP B ROOM158 ELEV -WORKING FLOORDECANT PUMP ROOM164 FT ELEV HVAC ROOMFUEL POOL COOLING AREA SR-1205RRWCU EQUIPMENT AND SAMPLING ROOMSSUPPLY FAN ROOM185 FT WORKING FLOORTURBINE BUILDING EXHAUST FILTER ROOMSBGT ROOM203 FT WORKING FLOOR203 FT REFUELING AIR SUPPLY ROOM228 FT REFUELING FLOORDRYWELL AND TORUSA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965253A,B 154A, B 152A,B 255A,B 156A, B 257A,B 158A,B 259A,B 163A,B 264A,B 1 and 262A,B 162A,B 161A,B 161A,B 165A,B 167A,B 169A,B 169A,B 168A,B; 67A,B 171A,B 166A,B 173A,B 173A,B 174A,B 1 and 256A,B & 1 and 257A,B(Torus Room Only)PROTECTEDSAFE SHUTDOWNSHT # PATHPREFIRE PLANDWG #TURBINE BUILDINGEAST CABLEWAYTURBINE BUILDINGWEST CABLEWAYTURBINE DECKSTAIRWAYSEAST CABLEWAY FOYERA-43965A-43965A-43965A-43965A-43965A-4396534A,BN/A81A,B87A,B, 88A, BN/A34A, B122222 V20Page 7 of 20SNC LAN E.I. HTCHI IPg 90 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 3_ Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 1 1 OF 81.0 PATHWAY 1 TO SHUTDOWNSystems Required1.1.1 RHR, Pump A; RHR Service Water Pump A.1.1.2 RClC1.1.3 SRVs, Gand H1.1.4 Plant Service Water, Pump A1.1.5 RHR and RClC Emergency Room Ventilation System, A Coolers1.1.6 RPV Instrumentation1.1.7 Containment Instrumentation1.1.8 Drywell Air Supply1.1.9 Diesel Generator and Associated Electrical Equipment1.1.10 MSIVs1.1.11 Diesel Building Ventilation1.1.12 Intake Structure Ventilation V20Page 8 of 20SNC LAN E.I. HTCHI lPg 98 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001 -1 13.1ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 2 1 OF 82.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR System, Pump B; RHR Service Water Pump B.2.2.2 RHR and HPCI Room Coolers, B Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air2.2.7 Diesel Generator and Associated Electrical Equipment2.2.8 HPCI2.2.9 Core Spray (for Fire Area 1203 only)2.2.10 SRVs, A and C.2.2.11 MSIVs2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 9 of 20SNC LANTE. I HATH IPg 106 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 3 I OF 83.0 PATHWAY 3 TO SHUTDOWN3.1 Systems Required3.2.1. RHR System, Pump B; RHR Service Water Pump B3.2.2. RHR and RCIC Room Coolers3.2.3. Plant Service Water, Pumps A and B.3.2.4. RPV Instrumentation3.2.5. Containment Instrumentation3.2.6. Drywell Air3.2.7. Diesel Generator and Associated Electrical Equipment3.2.8. RCIC3.2.9. SRVs, C and G.3.2.10. MSIVs3.2.11. Diesel Building Ventilation3.2.12. Intake Structure Ventilation V20Page 10 of 20SOUTERNNUCEAR I DOUMET TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 114DOCUENTTITL: IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-00 1-2 15.0EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 3-18-15 DATE:N/A SS M/PM N/A DATE N/A 3-18-2015TABLE OF CONTENTSSection Page1.0 CONDITIONS..................................................................................... 32.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.1 Control Building Ventilation Fans............................................................ 75.2 Ventilation Restoration....................................................................... 75.3 Control Building Specific Area Actions...................................................... 85.4 Oil Storage Tank Room ...................................................................... 85.5 Station Battery Rooms (FA 2005) ........................................................... 85.6 RPS Battery Rooms.......................................................................... 85.7 130 ft elev. Passageways, HVAC Room and Lab .......................................... 85.8 Annunciator Room ........................................................................... 95.9 Oil Conditioner Room (FA 2023) ............................................................ 95.10 RPS MG Set Room and Vertical Cableway................................................. 95.11 DC Switchgear Rooms....................................................................... 95.12 Switchgear Access Hallway & 600V Switchgear Room 2C............................... 105.13 600V Switchgear Room 2D................................................................. 115.14 Transformer Room 2CD .................................................................... 125.15 Main Control Room, Cable Spreading Room or Computer Room ....................... 135.16 Control Building 112 ft Elevation Working Floor, Corridor, and Annunciator Logic Cabinet(FA 0001).................................................................................... 145.17 Water Analysis Room (FA 2006)........................................................... 146.0 DIESEL GENERATOR BUILDING............................................................. 156.1 Diesel generator Building Specific Area Index ............................................ 156.2 DG Battery Rooms.......................................................................... 156.3 DG Day Tank Rooms ....................................................................... 166.4 DG Engine Rooms.......................................................................... 186.5 DG 2A Swgr Room 2E (2R22-S005) ...................................................... 196.6 DG 1B Swgr Room 2F (2R22-S006) ...................................................... 206.7 DG 2C Swgr Room 2G (2R22-S007) ...................................................... 217.0 YARD ............................................................................................ 227.1 Plant Yard Specific Area Index............................................................. 227.2 Intake Structure ............................................................................. 227.3 Nitrogen Storage Tank AREA.............................................................. 23 V20Page 11 of 20PAGE2 OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.07.4 Main or Unit Auxiliary Transformer......................................................... 237.5 Startup Auxiliary Transformer .............................................................. 237.6 Auxiliary Boiler .............................................................................. 237.7 Waste Gas Treatment Building....................,......................................... 237.8 High Voltage Switchyard ................................................................... 237.9 Circulating Water Pump Pit ................................................................ 238.0 REACTOR BUILDING .......................................................................... 248.1 Reactor Building Ventilation................................................................ 248.2 Reactor Building Specific Area Index...................................................... 248.3 North Half of Reactor Building Below 185 ft ............................................... 258.4 ASD Rooms ................................................................................. 278.5 South Half of Reactor Building, and All of the 185 ft and 203 ft Elevations ............. 288.6 Drywell....................................................................................... 389.0 TURBINE BUILDING ........................................................................... 399.1 Turbine Building Specific Area Index ...................................................... 399.2 Turbine Building............................................................................. 399.3 Turbine Building Unit 2 East Cableway (2104)............................................ 409.4 Turbine Building East Cableway Foyer .................................................... 409.5 Turbine Building Unit 1 East Cableway.................................................... 4110.0 RADWASTE BUILDING ....................................................................... 4210.1 Ventilation Charcoal Filter trains ........................................................... 4211.0 RECORDS ..................................................................................... 4312.0 COMMITMENTS............................................................................... 43Attachments1 SAFE SHUTDOWN ACTIONS ................................................................. 442 PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 ................................ 853 SAFE SHUTDOWN PATHS FOR UNIT 2 FOR UNIT 1 FIRES .............................. 894 SAFE SHUTDOWN COMPONENT LIST PATH 1I............................................ 905 SAFE SHUTDOWN COMPONENT LIST PATH 2 ............................................ 966 SAFE SHUTDOWN COMPONENT LIST PATH 3 ........................................... 1037 LINKS NORMALLY OPEN TO SUPPORT APPENDIX R ................................... 1108 REFERENCE DRAWINGS LIST.............................................................. 1119 PLACARDS FOR 2H11-P601................................................................. 11310 KEY MILESTONES FORA FIRE OR FIRE DRILL .......................................... 114 V20Page 12 of 20SOUTERN UCLER IPAGEPLAN E. .HACHJ250OF 114DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.08.3 NORTH HALF OF REACTOR BUILDING BELOW 185 FT. ELEVATION8.3.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.3. LII8.3.2 This fire area consists of the following fire zones, perform the steps applicable to the area:STEP ZONE PAGE8.3.3 North Half of Torus Room ............................................................ 258.3.4 RCIC Corner Room ................................................................... 258.3.5 Div I RHR and Core Spray Corner Room............................................ 268.3.6 130 Ft Elevation, North Half.......................................................... 26Reactor Building Stairwell NO ACTIONS *158 Ft Elevation, North Half NO ACTIONS ** No additional actions are required beyond normal fire response actions.8.3.3 North Half of Torus Room8.3.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. Eli8.3.4 RClC Corner Room8.3.4.1 Stop RClC Pump Rm Coolers.* 2T41-B004A El* 2T41-B004B El8.3.4.2 Close RClC Steam Supply Isol AND Steam Supply Line Isol Valves.* 2E51-F007 El* 2E51-F008 El V20Page 13 of 20PAGE280OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-2 15.08.5 SOUTH HALF OF REACTOR BUILDING, AND ALL OF THE 185 FT AND 203 FTELEVATIONS8.5.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.5. LI8.5.2 This fire area consists of the following fire zones,perform the steps applicable to the fire zone: LISTEP ZONE PAGE8.5.3 South Half of Torus Room........... ............................................... 278.5.4 CRD Corner Room.................................................................. 288.5.5 Div II RHR and Core Spray Corner Room (Southeast) ........................... 298.5.6 HPCI Room.......................................................................... 298.5.7 130 Ft Elevation, South Half........................................................ 308.5.8 158 Ft. Elevation South Half........................................................ 308.5.9 164 Ft HVAC Room................................................................. 318.5.10 Fuel Pool Cooling And Heat Exchanger Room.................................... 328.5.11 Fuel Pool and RWCU Precoat Equipment Area................................... 328.5.12 185 Ft Elevation Working Floor .................................................... 338.5.13 185 Ft HVAC Room................................................................. 348.5.14 Standby Gas Treatment Room..................................................... 348.5.15 203 Ft Working Floor................................................................ 358.5.16 203 Ft HVAC Room................................................................. 358.5.3 South Half of Torus Room8.5.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. L[]

V20Page 14 of 20SNC LAN E.I. HTCHI I Pg 85 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 1 OF 4*The Safe Shutdown Paths listed indicate the Safe Shutdown Train that has been analyzed for a firein the associated area. The Safe Shutdown Path (1 OR 2) least impacted by the fire in each areawas identified AND analyzed. It is assumed that only one path is available for shutdown for thepurpose of engineering analysis. This does NOT prevent Operator use of systems outside of theanalyzed path IFE they continue to function as required. For fire areas where protection of one pathCANNOT be achieved, such as the Main Control Room, Cable Spreading Room AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND~. analyzed.* Where circuit failures to analyzed path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are analyzed WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 4 (Path 1), Attachment 5 (Path 2) AND Attachment 6 (Path 3 -RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, may survive the fire. Circuit faults to unanalyzed equipmenthave NOT been evaluated.

V20Page 15 of 20SNC LANTE. I HATH IPg 86 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 2 OF 4ANALYZEDPREFIRE PLAN SAFE SHUTDOWNCONTROL BUILDING DWG # SliT# PATH112 Ft Elev Passageways, Hot Instrument Shop A-43965 5A, B 2and Service Air Compressor RoomsOil Storage Tank Room A-43965 1 6A, B 1 and 2Freight Elevator or Stairway A-43965 6A, B 2Station Battery Room 2A A-43965 1 7A, B 2Station Battery Room 2B A-43965 1 8A, B 1AC Inverter Room A-43965 20A, B 1 and 2RPS Battery Room 2A A-43965 21A, B 1 and 2RPS Battery Room 2B A-43965 22A, B 1 and 2Water Analysis Room A-43965 1 9A, B 1Unit 2 130 Ft Elev Switchgear Hallway A-43965 24A, B 2Switchgear Hallway Enclosure A-43965 35A, B 2All Other 130 Ft Elev Passageways A-43965 24A, B 2HVAC Room -130 Ft Elev A-43965 25A, B 2RPS MG Room A-43965 26A, B 1Vertical Cable Chase A-43965 26A, B 2Annunciator Room A-43965 36A, B 2Oil Conditioner Room A-43965 42A, B 2DC SWGR Room 2A A-43965 39A, B 2DC SWGR Room 2B A-43965 41A, B 1Rad Protection Area and Radwaste Lab A-43965 23A, B 2600V SWGR Room 2C A-43965 37A, B 2I600OV SWGR Room 2D A-43965 38A, B 12CD Transformer Room A-43965 40A, B 1CO2 Storage Tank Area A-43965 46A, B 2LPCI Inverter Room A-43965 47A, B 2Main Control Room A-43965 48A, B 3Cable Spreading Room A-43965 44A, B 3Computer Room A-43965 45A, B 3Control Room Roof A-43965 50A, B 2Control Bldg East Corridor, Cold Lab, and A-43965 7A, B 2Adjacent Rooms, El 112 9A, BSwitchgear Access Hallway A-43965 35A, B 1 V20Page 16 of 20SNC LANTE. I HATH IPg 87 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 3 OF 4DIESEL GENERATOR BUILDINGDG Building HallwayDG 2A Battery RoomDG 1 B Battery RoomDG 2C Battery RoomDG 2A Day Tank RoomDG 1 B Day Tank RoomDG 2C Day Tank RoomDG 2A Engine RoomDG 1B Engine RoomDG 2C Engine RoomDG 2A SWGR Room 2EDG lB SWGR Room 2FDG 2C SWGR Room 2GPREFIRE PLANDWG #A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SliT#5A, B19A, B11A, B23A, B18A, B10A, B22A, B20A, B12A, B24A, B21A, B25A, B26A, BANALYZEDSAFE SHUTDOWNPATH1 and 221 and 2121 and 2121 and 21221YARDCooling TowersIntake StructurePlant Service Water Valve Pit 2APlant Service Water Valve Pit 2BCondensate Storage Tank AreaNitrogen Storage Tank Area500KV Reactor SwitchyardMain 500 KV SwitchyardAuxiliary BoilerCirc Water Pump PITRadwaste Dilution Valve PitDiesel 2A Fuel Oil Storage TankDiesel 20 Fuel Oil Storage TankA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396677A, B79A, B, C, D27A, B50A, B51A, B44A, B42A, B84A, B82A, B61A, B53A, B59A, B73A, B73A, B1 and 21 and 22121 and 21 and 22N/A2221 V20Page 17 of 20SNC LAN E.I. HTCHI IPg 88 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-00 1-2 J 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 J 4 OF 4PREFIRE PLANDWG #ANALYZEDSAFE SHUTDOWNPATHREACTOR BUILDINGSHT#Div I RHR and Core Spray NE Corner RoomDiv II RHR and Core Spray SE Corner RoomCRD Corner RoomRClC RoomHPCI RoomTorus Room -South HalfTorus Room -North Half130 Ft Elev -South130 Ft Elev -NorthRecirc ASD Room 2ARecirc ASD Room 2BRWCU Pump A RoomRWCU Pump B Room158 Elev South -Working Floor158 Elev North164 Ft Elev HVAC RoomFuel Pool Cooling Heat ExchangerFuel Pool and RWCU Precoat Equip Area185 Ft Supply Fan Room185 Ft Working Floor185 Ft HVAC RoomSBGT Room ASBGT Room B203 Ft Elevation203 Ft ElevationRefuel FloorDrywellA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-4396599A, B 2101AB 1102AB 1100A.,B 2103A.,B 1105A. B 1104AB 2107AB 1106A, B 2113A, B 1land 2114A, B 1land 2111A, B 1111A, B 1110A, B 1109A, B 2112A, B 1116A, B 1116A, B 1118A, B 1116A, B117A,B 1118AB 1115A, B 1115A, B 1122A, B 1120A,B 121A,B 1123A, B 1land 2104A,B 105A,B 1 and 2(Torus Area Only)108A, B 1Main Steam ChaseTURBINE BUILDINGTurbine Bldg Fire Area 2101164 Ft Elev Turbine Deckand other Fire Area 0101Turbine Building Below Turbine DeckWest CablewayStairwaysTurbine DeckEast CablewayA-43965A-4396549A, B 87-90A, BA-43965A-43965A-43965A-43965A-43965124-1 32A,133-1 36A,N/A128A, BN/A134A, B43A, BBB2122221 V20Page 18 of 20SNC LANTE. I HATH 1Pg 90 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001-2 15.0ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 1 1 OF 61.0 PATHWAY I TO SHUTDOWN1.1 Systems Required1.2.1 RHR, Pump A, RHR Service Water Pump A1.2.2 RCIC1.2.3 SRVs1.2.4 Plant Service Water, Pump A1.2.5 Emergency Room Coolers1.2.6 RPV Instrumentation1.2.7 Containment Instrumentation1.2.8 Drywell Air (Nitrogen System, Drywell Pneumatic System)1.2.9 Diesel Generator 2A and Associated Electrical Equipment1.2.10 MSIVs, Inboard1.2.11 Core Spray Loop A (for spurious ADS WHEN RHR Loop "A" NOT available)1.2.12 Diesel Building Ventilation1.2.13 Intake Structure Ventilation1.2 System Components1.2.1 RHR, Pump A and RHR Service Water, Pump ARequiredNormal PATH 1MPL No Mode SSD Mode2E11-C001A OFF ON2E11-C002A OFF ON2E11-F003A 0 02E 11-F004A 0 02E11-F006A C C2E11-F007A 0 VAR2E1l-F010 C C2E11-F011A C C2E11-F015A C 02E11-F016A C C2E11-F017A 0 02E11-F026A C C2E11-F028A C C2E11-F047A 0 02E11-F048A 0 VAR2E11-F065A 0 0RequiredNormal PATH 1MPL No Mod._._e SSD Mode2E11-F068A C VAR2E11-F073A C C2E1 1-F104A C C2E11-F119A C C2E11-K600A ON ON2E11-K603A ON ON2E11-N007A ON ON2E11-N015A ON ON2E11-N017A C 02E11-N017C C 02E11-N082A ON ON2E11-N104A ON ON2E11-N682A C VAR2E11-R600A ON ON2E11-R602A ON ON2E11-R603A ON ON V20Page 19 of 20SNC LANTE. I HATH IPg 96 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 2 I OF 72.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR, Pump B, RHR Service Water Pump B2.2.2 Emergency Room Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)2.2.7 HPCI2.2.8 Diesel Generator 2C and Associated Electrical Equipment2.2.9 Core Spray, Loop B (for spurious ADS WHEN RHR Loop "B" NOT[ available)2.2.10 SRVs2.2.11 MSIVs, Outboard2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 20 of 20SNC LANTE. I HATH IPg 103 of 114DOCMET ITE:DOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 6 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 3 1OF 73.0 PATHWAY 3 TO SHUTDOWN (REMOTE SHUTDOWN SYSTEMS)3.1 Systems Required3.2.1 RHR, Pump B, RHR Service Water Pump B3.2.2 Emergency Room Coolers3.2.3 Plant Service Water, Pump B3.2.4 RPV Instrumentation3.2.5 Containment Instrumentation3.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)3.2.7 RCIC3.2.8 Diesel Generators 2A and 2C and Associated Electrical Equipment3.2.9 SRVs3.2.10 MSIVs, Inboard3.2.11 Diesel Building Ventilation3.2.12 Intake Structure Ventilation V21Page 1 of 14. ITheMinmumSteam Cooling RPV Water Level for Hatch is: -180 inches. (Both5. The Minimum Steam Cooling RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. The temperature of the water injected into the RPV is 1 000F.6. Plant-specific data required to calculate the Minimum Steam Cooling RPV WaterLevel is as follows:a. Minimum active fuel length fraction which must be covered to maintain peakclad temperature below 1 5000F with injection.b. Active fuel lengthc. Water level at the bottom of the active fuelE. Minimum Zero-Injection RPV Water Level(LT 31) (LCT 31)1. The Minimum Zero-Injection RPV Water Level is defined to be the lowest RPVwater level at which the covered portion of the Reactor core will generate sufficientsteam to preclude any clad temperature in the uncovered portion of the core formexceeding 1 8000F. This Water Level is utilized to preclude significant fuel damageand hydrogen generation for as long as possible.2. This is the level at which Steam Cooling Without injection is used in the EOPs.A cold shutdown rod configuration must exist to use this core cooling method.3. The Minimum Zero-Injection RPV Water Level for Hatch is: -195 inches.(Both units)4. The Minimum Zero-Injection RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. No water is injected into the RPV.EOP-CURVES-LP-20306 Ver 3.0 GRAPH 2V22Page 1 of 2UNIT 1HEAT CAPACITY TEMPERATURE LIMIT0[-(i-TORUS WATER LEVEL (in)NOTE: May use SPDS Emergency Displays in place of this Graph.* Safe operating is below the applicable pressure line.

V22Page 2 of 2SGRAPH 2Heat Capacity Temperature LimitEI-2602402202O00180160140120._'C')I..'IC')0Ra-x.I8098 120 140 160 180193200Torus Water Level (in)Note: May use SPDS in place of this GraphREQUIRED if above curve for existing RPV pressEOP-CURVES-20306FIG 2Page 61 of 75 V23Page 1 of 4Mare Condenser Offgas3.7.63.7 PLANT SYSTEMS3.7.6 Main Condenser OffgasLCO 3.7.6tiT e gross gamma actvity rate of the noble gases measured at the maincondenser evacuation system pretreatmentl monitor station shall be240 mCi/seond. ,MODE 1,MODES 2 and 3 with any main steam line not isolated and steam jet airejector (SJAE) in operation.APPLICABILITY:ACTIONS___________ _____ ___CONDITION REOUIRED ACTION COMPL=ETION TIMEA. Gross gamma activity rate A.1 Restore gross gamma 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months sof the noble gases not activity rate of the noblewithin limit, gases to limit.B8 Required Action and B. 1 Isolate all main steam 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sassociated Completion linesTime not met.OR8.2 Isolate SJAE 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sORRB.3.1 Be in MODE 3 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sANDB,3.2 Be in MODE 4. 36 hootsHATCH UNIT 23.7-16HATC UNI 2 37-16Amendment No. 135 CDCD0(0CDN, 0-9CD V23, Page 4 of 4SU3 Reactor coolant activity greater than Technical Specification allowable limits.Operating Mode:Power OperationStartupHot StandbyHot Shutdown(1 OR 2)Emergency Action Levels:1. Pretreatment Radiation Monitor reading greater than 240,000 pCi/sec for greater than60 minutes.According to Tech. Spec. Bases 3. 7.6 page B3. 7-31 and Tech. Spec. section 3. 7.6page 3. 7-16, the gross gamma activity rate of the noble gases measured at the maincondenser evacuation system pretreatment monitor station shall be <.240mCi/secondor <240, O00pCifsecond. According to 64C1-0CB-006-1/2 procedures the offgaspretreatment radiation monitors are 1/2D1 1-K601 and 1/2D1 1-K602OR2. Sample analysis indicates that the reactor coolant specific activity is EITHER:* Greater than 0.2 pCi/gm and less than or equal to 2.0 pCi/gm doseequivalent 1131 for greater than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .* Greater than 2.0 pCi/gm dose equivalent 1131.According to Tech. Spec. Bases 3. 4.6 page B3.4-25 and Tech. Spec. section 3. 4.6page 3.4-11, the specific activity of the reactor coolant shall be limited to DOSEEQUIVALENT 1-131 specific activity 0.2 IJCi/gm. A condition >0.2 pCi/gm but <2.OIJCi/gm must be restored within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . A condition > 2pCi/gm requires immediateaction, V24Page 1 of 1RCS Specifi Activity3.4.63.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 RCS Specific ActivityLCO 3.4.6Thre specifi activty of the reactor coolant shag be limited to DOSEEQUIVALEFNT 1-131 speific activit 0.2 pC~igm.APUCBIUTrY:MODE 1,MODS 2 and 3 with any m'aui steam line not isolated.ACTIONSCO,,NDmON REQUIRED ACTION COMPLETION TIMEA.Reacto colaspecifi NOTESacbvtty 0.2 &aCim and LCO 3.0.4.c is apl:iicable.1 2.0 DOSElEQUIVALENT 1-131.A.1 Determine DOSE Once per 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months sEQUIVALENT 1-131.ANDA.2 Restore DOSEEQUIALENT 1-131 toB. Required Ac~tion an B.1 Determine DOSE Once per 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months sassociated Completion EQUIVALENT 1-131.Time of Cocst A notQR B2.1 Isolate all main steam 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sReactor coolant spciiactivity >2.0 DOSE OEQUIVALENT 1-131.B22.1 BeminMODE 3. 12 IurS8222 Be in MODE 4. 36 hour4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months sHATCH UNIT 23.4-11HATH UIT 34-1 AmndmntNo. 210 V25Page 1 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (Refs. 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation and thecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 1 .-3RVSOB 3.4-13REVISION 0 V25Page 2 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment canI(continued)HATCH UNIT 1 B341 EIIN5B 3.4-14REVISION 59 V25Page 3 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._IWith RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 1 .-5RVSOB 3.4-15REVISION 0 V25Page 4 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (References 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation andthecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 2 B341 EIIN7B 3.4-14REVISION 77 I V25Page 5 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment can(continued)HATCH UNIT 2 B341 EIIN7B 3.4-15REVISION 77 I V25Page 6 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in' anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._1!With RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 28341REION7B 3.4-16REVISION 77 V1 8Page 1 of 10SOUTHERN NUCLEARIPLANT El. HATCHPAGE 9 OF 30DOUMNTTILE t DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL t 34AB-T22-003-1 5.14ATTACHMENT 2 ATT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1G31-R604) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1H11-P614, 1G31-R604 Value Value0F o158' ELEVATION AREA (RWCU)101 B Pump Room (1G31-N016D) 150 212.5102 B Pump Room DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Room (1G31-N016B) 150 212.5104 Hx Room DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B (1E11-N009B) 150 212.5108 RHR/CS B DIFF(1E11-N030B/1E11-N029B) 40 98HPCl ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245110 HPCI VENT AIR DIFF (1E41-N029B/1E41-N028B) NA NA(not used)RCIC ROOM AREA111 Emer Area CIr (1 E5I-N023B) 167.5 310112 RCIC VENT AIR DIFF (1E51-N022B/1E51-N021 B) NA NA(not used)TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1E51-N025D) 167.5 212.5115 VENT AIR DIFF (1E51-N027B/1E51-N026B) 42 102116 VENT AIR DIFF (1 E51-N027D/1 E51-N026D) 42 102HPCI PIPE PENETRATION ROOM117 1E41-N046B 150 212.5Posted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 2 of 10PAGE 10 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 3 ATTACH. PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1 G31 -R608) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1IH11-P614, 1G31-R608 Value ValueoF o158' ELEVATION AREA (RWGU)101 A Pump Room (1G31-N016C) 150 212.5102 A Pump Room DIFF (1G31-N022B/1G31-N023B) 67 98103 Hx Room (1G31-N016E) 150 212.5104 Hx Room DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF (1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A (lE1 1-N009A) 150 212.5108 RHRICS A DIFF (1EI11-N030A/1 E11-N029A) 40 98HPCI ROOM AREA109 Pump Room (1E41-N024) 167.5 245110 Emer Area CIr (1 E41 -N030A) 167.5 245111 HPCl VENT AIR DIFF (1 E41-N029A/11E41-N028A) NA NA(not used)_________RClC ROOM AREA112 Pump Room (1E51-N011) 167.5 310113 Emer Area CIr (1E51-N023A) 167.5 310114 RCIC VENT AIR DIFF (1 E51-N022A/1 E51-N021A) NA NA(not used)TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-N025C) 167.5 212.5117 VENT AIR DIFF (1 E51-NO26AI1 E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1 E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm TnI 1B21-N014 192.5 300120 1B21-N016AN0O16B DIFF 60 150HPCI PIPE PENETRATION ROOM 150 212.5121 1E41-N046APosted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 3 of 10PAGE 27 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE ]DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2Max MaxSECONDARY CONTAINMENT TEMPNoml Sfon IHI1-P614, 1G31-R604 0158' ELEVATION AREA (RWCU)101 B Pump Rm (1G31-N016D) 150 212.5102 B Pump Rm DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Rm (1G31-N016B) 150 212.5104 Hx Rm DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B(1E11-N009B) 150 212.5108 RHR/CS B DIFF (1E11-N030B/1E11-N029B) 40 98HPCI ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245RCIC ROOM AREA111 Emer Area Clr (1 E51-N023B) 167.5 310TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1 E51-N025D) 167.5 212.5115 Vent Air DIFF (1E51-N027B/1E51-N026B) 42 102116 Vent Air DIFF (1E51-N027D/1E51-N026D) 42 102HPCl PIPE PENETRATION ROOM117 1E41-N046B 150 212.5RDG RDG1 23Reference 34AB-T22-003- 1MGR-0009 Rev 5.0 Vi18Page 4 of 10PAGE 28 OF 30SOUTHERN NUCLEARIPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT -9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP Max Maxon 1H11-P614, 1G31-R608 Normal Safe158' ELEVATION AREA (RWCU)101 A Pump Rm (1G31-N016C) 150 212102 A Pump Rm DIFF (1G31-N022BI1E51-N023B) 67 98103 Hx Rm (1G31-N016E) 150 212.5104 Hx Rm DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF(1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A(1E11-N009A) 150 212.5108 RHR/CS A DIFF (1E11-N030A/1E11-N029A) 40 98HPCl ROOM AREA109 Pump Rm (1E41-N024) 167.5 245110 EmerArea Clr(1E41-N030A) 167.5 245RCIC ROOM AREA112 Pump Rm (1E51-N011) 167.5 310113 EmerArea CIr (1E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-NO25C) 167.5 212.5117 VENT AIR DIFF (1E51-N026A11E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm Tnl (1B21-N014) 192.5 300120 1B21-N016A/N016B DIFF 60 150HPCI PIPE PENETRATION ROOM121 1E41-N046A 150 212.5I/RDG RDG RDG1 2 3I________Iec 4B-2-0-MGR-0009 Rev 5.0 V18Page 5 of 10PAGE 29 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL 34AB-T22-003-1 5.14ATTACHMENT 10 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT PARAMETERS 1 OF 1Imax 14" aow8rTelw.Ir Irt' 3TabowSTe~ev.t#' aovSe lteev.DIAGONALAREA150212.5I.IV ROOMAIEA wI' h svIo"fl vi" IT 71e,CO4hNMENREFA RADIATIONIMONITORS I [g~11.SS 1211UV~jteVaeIEREL FLO(F AREA1Reathe.J iee (1D21-KG00A) 50 10002 a u(IO141-01 B) 50 10(003 P.uuI o(1O21-K60lD) 50 10004 Dr~weIl 50 10005 SpeltFtmlPool&New~uelStcrage(1D21.K501M 50 10005RB20Wor~ru(1D21K0 X) 50 7 SpentFuel PoC DeuinvEquip{1O21.01C) 150 I1Q000eFu.PocDsrmin, Pmn(1D21.K17) 50 10 ___9 R81irWokArea(1D214K601K) 50 1 00010 RxbSarjiRzdkue (ID214K601L) 50 1 000)11 50 IOQ0012 NothCRVHCU(1021-IQD1P) 50 I100014 R8130N.E~odinku(1D21.K601G) 50 I100015 50 ]1000 __ELEVATION SOUTH AREA16 50 100017 SoutthCAOHCJ(1D2FH(0tN) 50 1000 _18 RCCEEupSWDmgna(1O21.KO1V) 50 I1000NORfN"TI~LAOA AREA19 CR)PumpiWOIagvnI(1D21.(801W) 50 I1000NOfES G4LAREA20 CS&RJIRN~.Edg(1D21-KIE01Y) 50 1000SOUT~fJST ENA-(NAL ARE --_ -21 CS&Rk-IlS,,EDigoza{IDT2.K6O1R) 50 1 (000!J7 ELEVATION AREA ET22 HFOTuwtmieAlui1D214t01T) 150 I10(001OP114S-~1933~I l=l 1I34AB-T22-O03-1OPS-1 933MGR-0009 Rev 5.0 V1 8Page 6 of 10PAGE 9 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 2 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 1(2G31-R604)_________MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H11-P614, OPERATING OPERATING2G31-R604 VALUE VALUE°F °F158' ELEVATION AREA (RWCU)101. B pump room (2G31-N016B) 150 215102. B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103. Hx Room (2G31-N016D) 150 215104. Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105. Valve Nest (2G31-N016F) 150 215106. Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 99SOUTHEAST DIAGONAL AREA107. RHR/CS B (2E11-N009B) 150 190108. RHR/CS B DIFF (2E11-N030B/2E11-N029B) 40 74HPCI ROOM AREA109. Emer area clr (2E41-N030B) 167.5 245110. HPCl vent air DIFF (2E41-N029B/2E41-N028B) NA NA(not used)______ ____RClC ROOM AREA111. Emer Area CIr (2E51-N023B) 167.5 310112. RCIC vent air DIFF (2E51-N022B/2E51-N021B) NA NA(not used)______ ____TORUS ROOM AREA113. Northwest Wall (2E51-N025B) 167.5 212.5114. Southeast Wall (2E51-N025D) 167.5 212.5115. Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116. Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117. 2E41-N046B 167.5 212.5 Vi18Page 7 of 10PAGE 10 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 3 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (2G31 -R608) 1 OF 1MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H1 1-P614, OPERATING OPERATING2G31-R608 VALUE VALUE°F °F158' ELEVATION AREA (RWCU)101. A Pump Room (2G31-N016A) 150 215102. A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 99103. Hx Room (2G31-N016C) 150 215104. Hx Room DIFF (2G31-N023C/2G31-N022C) 67 99105. Phase Sep Rm (2G31-N016E) 150 215106. Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 99NORTHEAST DIAGONAL AREA107. RHR/CS A (2E1 1-N009A) 150 215108. RHR/CS A DIFF (2E11-N030AN2E11-N029A) 40 74HPCI ROOM AREA109. Pump Rm (2E41-N024) 167.5 245110. Emer Area CIr (2E41-N03OA) 167.5 245111. HPCI Vent Air DIFF (2E41-N029A/2E41-N028A) NA NA(not used)__________RCIC ROOM AREA112. Pump Rm (2E51-N011) 167.5 310113. Emer Area CIr (2E51-N023A) 167.5 310114. RCIC Vent Air DIFF (2E51-N022A12E51-N021A) NA NA(not used)TORUS ROOM AREA115. West Wall (2E51-N025A) 167.5 212.5116. Northeast Wall (2E51-N025C) 167.5 212.5117. Torus Vent Air DIFF (2E51-N027A/2E51-N026A) 42 98118. Torus Vent Air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119. Main Steam Tunnel (2B21-N014) 192.5 310120. Main Stm Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150HPCI PIPE PENETRATION ROOM121. 2E41 -N046A 167.5 212.5 V18Page 8 of 10PAGE 30 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT _9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2SECONDARY CONTAINMENT TEMPMMAon 2H11-P614, 2G31-R604 NORMALj SAFE158' ELEVATION AREA (RWCU)101 B pump room (2G31-N016B) 150 215102 B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103 Hx Room (2G31-NO16D) 150 215104 Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105 Valve Nest (2G31-N016F) 150 215106 Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 9SOUTHEAST DIAGONAL AREA107 RHR/CS B (2E11-N009B) 150 J190108 RHR/CS B DIFF (2E1 1-N030B/2G31-N029B) 40 J 74HPCI ROOM AREA109 Emer Area CIr (2E41-N030B) I67.5 245RCIC ROOM AREA111 Emer Area CIr (2E51-N023B) 16. 1TORUS ROOM AREA113 Northwest Wall (2E51-N025B) 167.5 212.5114 Southeast Wall (2E51-N025D) 167.5 212.5115 Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116 Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117 2E41-N046B Ii7.5I 212.5Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 SOUTHERN NUCLEARPLANT E.I. HATCHVi18Page 9 of 10PAGE 31 OF 37DOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP MAX MAXon 2H11-P614, 2G31-R608 NORMAL[ SAFE158' ELEVATION AREA (RWCU)101 A Pump Room (2G31-N016A) 150 21102 A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 9103 Hx Room (2G31-N016C) 150 21104 Hx Room DIFF (2G31-N023C/2G31-N022C) 67 9105 Phase Sep Rm (2G31-N016E) 150 21106 Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 9NORTHEAST DIAGONAL AREA107 RHR/CS A (2E1 1-N009A) 150 21108 RHR/CS A DIFF (2E11-N030AI2E11-N029A) 40 174HPCl ROOM AREA109 Pump Rm (2E41-N024) 167.5 245110 Emer Area Clr(2E41-N030A) 167.5/ 245RClC ROOM AREA112_Pump Rm_(2E51-N011) 167.5 _310113 Emer Area Clr (2E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (2E51-N025A) 167.5 212.5116 Northeast Wall (2E51-N025C) 167.5 212.5117 Torus vent air DIFF (2E51-N027A12E51-N026A) 42 98118 Torus vent air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119 Main Steam Tunnel (2B21-N014) 192.5 310120 Main Steam Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150RDG RDG1 RDG1 2 3-B_HPCl PIPE PENETRATION ROOMI121 2E41,N046A [167.5 212.5_Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 V1 8Page 1 0 of 10PAGE 35 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 1"1 ATTACHMENT PAGE:TITLE: SECONDARY CONTAI NMENT PARAMETERS 1 OF 1Table 4 o'9tA~hG~iWAfliI I C0NbleN 5 A101102AREA WATER LEVELSMax NanulMaxSafe.___ 4" r/5T'sia 33 isv .1.AREA4"iow ST ealeion!$"o8T 1ev'.4icvelTelwian 27.bovel7'elw.diov.STal.vglwit#' above $'t' 4" isve 8'uleiion14" isy rr sh,4 aov 57' ekydontt" above 37' .ev.Table 6 ARIA MOR10.3yaw awS UUHd113 l 51-N058) I167.5 212.5114 Sou WlbeI (2E514NU50) l167.5 212.5116 ToqusM VtOIFF 42 901 A Pw~own%2;G31.#408Ao mpRoooN2G314 t3Phu Sep Rm(2m1.N01E)Va15067'so57150RiVa21599215982151 Reac had (2D21-K601A) 50 1Q0003 SfouIlo&NswFu l~g.(2f21.KBO1M) 50 10004 ahFboor(2D214(SI11K) 5o 10o0G Reeor Vesse!RFloor (2Q21.K811 L) 50 1Q00063 (2D214,SO1T) 50 10]007 HV o¢W 50 1008 Spn u olPsaea 50 10009 RB 18 qelegIoor(2O21..KO0R) 50 100010 R81W Samispuue t.lme(221.(8O1S) 50 1Q000I'I R818 cou~rol pa-.(2O21-K601U) 15O t000__13 S reaIW (2D21.(501D) 50 1000__15Dean um eupmntronara 50 1000__`10001307 ELEVATION ARE.A (NSRUThWSN(R11PMB(2T2IMOIF) L AO RtOA217 50 .100022 RC1S.W4~odgAii(2D21,,K601X) 50 .100023 cs&rRls~dagoi(2V214WO1Y) 150 1000O115 16+7.5 21 21542 198l34AB-.T22-003-2OPS-1932OPS-1 932 V19Page 1 of 4PAGE 2 OF 3SOUTHERN NUCLEARPLANT E.I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:ARP'S FOR CONTROL PANEL 2H1 1-P657, 34AR-657-901-2 I 23.1ALARM PANEL 1UNIT 22H11-P657 -1 (LEFT)657-001 657-002 657-00.3 557-004 57-005 657-006 657-007 657-008 657-009657-019 657-020 657-021 57-02 657-023 657-024 657-025 657-026 657-027657-037 657 -03 6 57-03;;57-040 6 7-041 657-042 657-043 657-044 657-045657-055 657-05S G57 057 657-058 -5705 657-060 657-061 657-062 657-063657-07 657-074 657-075 657-0Th 657-77 657-07 657-079 657-080 657-081657-091 57 0 2 657-093 557-094 657-095 657 096 65-097 657-098 657-0992H11-P657 -1 (RIGHT)657-010 657-011 G57-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 ss57-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 65 7-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-0B3 65-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108Level Of Use ARPsCONTINUOUS ALLREFERENCE NoneINFO None Vi19Page 2 of 41.0 IDENTIFICATION:ALARM PANEL 657__ _______SEISMIC* INSTRUMENTATIONTRIGGEREDDEVICE: SETPOINT:2L51-N022 0.08 g horizontal, 0.54 g vertical2L51 -N024 0.18 g horizontal, 0.063 vertical2.0 CONDITION: 3.0 CLASSIFICATION:[ EQUIPMENT STATUSMotion has been detected in Unit 2 Reactor Building on4.LOAINelevation 87' or 185' 4 H0 LOCATION5.0 OPERATOR ACTIONS:5.1 At Panel 1 Hi11-P701, check for further indications of a seismic eventby monitoring Peak Shock Annunciator, 1 L51-R620,for 12.7 Hz amber lights (> 0.08g, OBEY) and 12.7 Hz red lights (> 0.15g, DBE). LII5.2 Refer to Seismic Instrumentation Earthquake Response Manual, SX-18271,for guidance in analyzing seismic data. LI5.3 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. LI5.4 Enter NMP-EP-1 10, Emergency Classification Determination and Initial Action. LI5.5 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. LI6.0 CAUSES:Seismic event

7.0 REFERENCES

8.0 TECH. SPECS./TRMIODCMIFHA:7.1 H-16319, Seismic Measurement Equip Control TRM T3.3.6 Seismic MonitoringPanel & Instrumentation. Instrumentation7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-048-2VER 4.1MGR-0048 Ver. 5.0 Vi19Page 3 of 4UNIT 1IH11-P657 -1 (RIGHT)657-010 657-011 657-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 657-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 657-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-083 657-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108RECORDSThere are no records generated by the procedureCOMMITMENTSNONEMGR-0001 Ver. 4 V19Page 4 of 41.0 IDENTIFICATION:ALARM PANEL 657________SEISMIC PEAKSHCKRECORDERJDEVICE: SETPOINT:1 L51-Vbc-R620 Not available5.0 OPERATOR ACTIONS:5.1 At Panel 1~ H1-P701, check for further indications of a seismic event,by monitoring 1L51-Vbc-R620, Peak Shock Annunciators,for 12.7 Hz amber lights (> 0.08g, OBE) AND 12.7 Hz red lights (_? 0.15g, DBE). El5.2 IF no other indications of a seismic event are present, check the following:* Peak Shock Annunciator, 1L51-vbc-R602, plugged in on Panel 1H1 1-P701 El* BRKR 3 on 120/208V Essential AC Cab, 1R25-S065 El5.3 Refer to SX-18271, Seismic Instrumentation Earthquake Response Manual,for guidance in analyzing seismic data. El5.4 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. El5.5 Enter 73EI-EIP-001-0, Emergency Classifications and Initial Actions. El5.6 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. El6.0 CAUSES:6.1 Seismic event6.2 Power failure

7.0 REFERENCES

8.0 TECH. SPEC.ILCO:7.1 H-16319, Seismic Measurement Equipment Control Unit 2, TRM T3.3.6 Seismic MonitorsPanel and Instrumentation.7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-066-1IVer. 3.0MGR-0048 Ver. 5AG-MGR-75-1101 V20Page 1 of 20SOUTERN UCLAR DCUMNT TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 118DOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-1 13.1EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 8-1 1-14 DATE:N/A SSM /PM N/A DATE N/A 9-11-141.0 CONDITIONSA fire exists at Plant E. I. Hatch. This procedure provides information AND actions necessary tomitigate the consequences of fires AND to maintain an operable shutdown train following firedamage to specific areas.TABLE OF CONTENTSSection Paae2.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.4 112 FT. ELEVATION ......................................................................... 75.5 OIL STORAGE TANK ROOM ............................................................... 75.6 STATION BATTERY ROOMS ............................................................... 85.7 RPS BATTERY ROOMS..................................................................... 85.8 130 FT ELEV. PASSAGEWAYS, HVAC ROOM, HP AREA, RADWASTE LAB ......... 85.9 RPS MG SET ROOM ........................................................................ 85.10 OIL CONDITIONER ROOM ................................................................. 95.11 DC SWITCHGEAR ROOMS................................................................. 95.12 600V SWITCHGEAR ROOM iC ............................................................ 95.13 600V SWITCHGEAR ROOM 1D........................................................... 105.14 TRANSFORMER lCD ROOM ............................................................. 105.15 MAIN CONTROL ROOM, CABLE SPREADING ROOM OR COMPUTER ROOM ....115.16 CONTROL ROOM ROOF .................................................................. 135.4 112 FT. ELEVATION........................................................................ 146.0 DIESEL GENERATOR BUILDING ............................................................. 156.2 DG BATTERY ROOMS..................................................................... 156.3 DG DAY TANK ROOMS.................................................................... 166.4 DG ENGINE ROOMS ...................................................................... 176.5 DG 1A SWGR ROOM 1E (1R22-S005).................................................... 186.6 DG lB SWGR ROOM iF (1R22-S006).................................................... 196.7 DG 1C SWGR ROOM 1G (1R22-S007)................................................... 207.0 YARD ............................................................................................. 217.2 COOLING TOWER ......................................................................... 227.3 INTAKE STRUCTURE...................................................................... 227.4 CONDENSATE STORAGE TANK AREA ................................................. 227.5 NITROGEN STORAGE TANK AREA...................................................... 23 SOUTHERN NUCLEARPLANT E. I. HATCHIV20Page 2 of 20PAGE2 OF 118DOCMEN TTLE IDOCUMENT NUMBER: IVERS ION NO:FI RE PROCEDURE 34AB-X43-001-.1 j 13.17.6 MAIN OR UNIT AUXILIARY TRANSFORMER............................................ 237.7 STARTUP AUXILIARY TRANSFORMER................................................. 237.8 AUXILIARY BOILER........................................................................ 237.9 COOLING TOWER SWITCHGEAR HOUSE.............................................. 237.10 WASTE GAS TREATMENT BUILDING................................................... 237.11 FIRE PUMP HOUSE........................................................................ 237.12 CONDENSATE DEMINERALIZER BUILDING (MUD HOUSE).......................... 237.13 CHLORINE BUILDING...................................................................... 247.14 SECURITY CAS BUILDING................................................................ 247.15 CIRCULATING WATER PUMP PIT ....................................................... 247.16 RECOMBINER BUILDING ................................................................. 247.17 TSC247.18 HIGH VOLTAGE SWITCHYARD .......................................................... 247.19 DISCHARGE STRUCTURE................................................................ 247.20 MAIN STACK................................................................................ 247.21 DEEPWELL PUMP HOUSE................................................................ 247.22 HYDROGEN/OXYGEN BULK STORAGE FACILITY..................................... 247.23 HYDROGEN/OXYGEN SUPPLY INTERMEDIATE VALVE STATION.................. 257.24 HYDROGEN/OXYGEN TURBINE BLDG ISOLATION VALVE STATION............... 257.25 HP/CHEMISTRY FILTER TRAIN (NORTH SIDE OF SECURITY CAS BLDG)......... 267.26 ISFSI / DRY STORAGE AREA (SOUTH OF PROTECTED AREA) ..................... 268.0 UNIT 1 REACTOR BUILDING.................................................................. 278.3.3 Torus Room, South Half............................................................... 278.3.4 RClC Room ............................................................................ 288.3.5 Div I RHR and Core Spray Corner Room ............................................ 288.4.3 Torus Room, North Half ............................................................... 298.4.4 CRD Room............................................................................. 308.4.5 Div II RHR and Core Spray Corner Room............................................ 318.4.6 HPCl Room............................................................................. 318.4.7 130 Ft Elevation, North Half........................................................... 328.4.8 158 Ft Elevation, North Half........................................................... 338.4.9 164 Ft HVAC and SBGT Room ....................................................... 348.4.10 Fuel Pool Cooling and Heat Exchanger Room....................................... 378.4.11 RWCU Equipment Room.............................................................. 378.4.12 203 Ft................................................................................... 388.5 REClRCULATION PUMP / ASD AREA MG SET ROOM ................................ 388.6 DRYWELL................................................................................... 399.0 TURBINE BUILDING ........................................................................... 409.2 TURBINE BUILDING OR WEST CABLEWAY............................................ 409.3 EAST CABLEWAY.......................................................................... 419.4 EAST CABLEWAY FOYER ................................................................ 4110.0 RADWASTE BUILDING ........................................................................ 4211.0 RECORDS....................................................................................... 4312.0COMMITMENTS ................................................................................ 43 V20Page 3 of 20SNC PANT .I.HATC I I Pg 85 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 1 OF 5*The Safe Shutdown Paths listed below indicate the Safe Shutdown Train that has been protectedfor a fire in the associated area. The Safe Shutdown path (1 OR 2) least impacted by the fire ineach area was identified AN..._D protected. It is assumed that only one path is available for shutdownfor the purpose of engineering analysis. This does NOT prevent operator use of systems outside ofthe protected path, IF they continue to function as required. For fire areas where protection of onepath cannot be achieved, such as the Main Control Room, Cable Spreading Room, AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND protected from the fire area.* Where circuit failures to protected path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are protected WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 3 (Path 1), Attachment 4 (Path 2), AN Attachment 5 (Path 3 OR RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, although NO_._I specifically protected OR analyzed, may survivethe fire. Circuit faults to unanalyzed equipment have NOT been evaluated.

V20Page 4 of 20SNC LAN E.I. HTCHI IPg 86 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDUREI 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -UI 2 OF 5PREFIRE PLANDWG #CONTROL BUILDING112 FT. ELEV PASSAGEWAYS ORSERVICE AIR COMPRESSOR ROOMOIL RESERVOIR ROOMFREIGHT ELEVATOR OR STAIRWAYAC INVERTER ROOMSTATION BATTERY ROOM 1ASTATION BATTERY ROOM 1 BRPS BATTERY ROOM 1ARPS BATTERY ROOM lBWATER ANALYSIS ROOM ORHOT INSTRUMENT SHOPUNIT 1 130 FT ELEV PASSAGEWAYSHVAC ROOM -130 FT ELEVRPS MG ROOMVERTICAL CABLE CHASEANNUNCIATOR ROOMOIL CONDITIONER ROOMDC SWGR ROOM 1ADC SWGR ROOM lBHEALTH PHYSICS AREA ORRADWASTE LAB600V SWGR ROOM 1C600V SWGR ROOM 1DTRANSFORMERS ROOM lCDCO2 STORAGE TANK AREAMAIN CONTROL ROOMCABLE SPREADING ROOMCOMPUTER ROOMA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43 965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965SHT #5A, B10A,B6A, B13A,B11A,B12A,B15A, B1 4A, B8A, B24A,B25A, B26A,B26A,B27A,B33A, B30A, B32A,B23A, B28A,B29A,B31A,B46A, B48A,B44A,B45A, BPROTECTEDSAFE SHUTDOWNPATH21 and 221211 and 21 and 212212222122122REMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMS2CONTROL ROOM ROOFA4365A,A-43965 50A, B V20Page 5 of 20SNC LANTE. I HATH IPg 87 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE1 34AB-X43-001-1 13.1ATTACHMENT 2 Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 3 OF 5DIESEL GENERATOR BUILDINGDG BUILDING HALLWAYDG 1A BATTERY ROOMDG 1 B BATTERY ROOMDG lC BATTERY ROOMDG 1A DAY TANK ROOMDG 1 B DAY TANK ROOMDG 1 C DAY TANK ROOMDG 1A ENGINE ROOMDG lB ENGINE ROOMDG 1C ENGINE ROOMDG 1A SWGR ROOMDG 1B SWGR ROOMLDG lC SWGR ROOMPREFIRE PLANDWG #A-43966A-43966A-43966A-43 966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SHT #5A, B15A,B11A,B7A,B1 4A, B10A, B6A, B16A, B12A, B8A,B1 7A, B13A, B9A, B1 and 221 and 2121 and 21221221PROTECTEDSAFE SHUTDOWNPATHYARDCOOLING TOWERSINTAKE STRUCTUREPLANT SERVICE WATER VALVE PIT 2APLANT SERVICE WATER VALVE PIT 2BCONDENSATE STORAGE TANK AREANITROGEN STORAGE TANK AREATRANSFORMERSAUXILIARY BOILERCIRC WATER PUMP PITFIRE PROTECTION PUMP HOUSE,WEST AREAA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396674A, B thru 76C,D27A, B50A, B51A,B43A,B41 A, B56A, B61A,B52A,B46A,B1 and 21 and 221111 and 2NA21 and 2 V20Page 6 of 20SNC LANTE. I HATH IPg 88 of 118DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-00 1-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 4 OF 5REACTOR BUILDINGPREFIRE PLANDWG #PROTECTEDSAFE SHUTDOWNPATHSHT #51A,BDIV I RHR AND CORE SPRAY SECORNER ROOMDIV II RHR AND CORE SPRAY NECORNER ROOMCRD CORNER ROOMRCIC ROOMHPCI ROOMTORUS ROOM -SOUTH HALFTORUS ROOM -NORTH HALF130 FT ELEV -SOUTH130 FT ELEV -NORTHREClRC ASD ROOM 1ARECIRC ASD ROOM lBRWCU PUMP A ROOMRWCU PUMP B ROOM158 ELEV -WORKING FLOORDECANT PUMP ROOM164 FT ELEV HVAC ROOMFUEL POOL COOLING AREA SR-1205RRWCU EQUIPMENT AND SAMPLING ROOMSSUPPLY FAN ROOM185 FT WORKING FLOORTURBINE BUILDING EXHAUST FILTER ROOMSBGT ROOM203 FT WORKING FLOOR203 FT REFUELING AIR SUPPLY ROOM228 FT REFUELING FLOORDRYWELL AND TORUSA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965253A,B 154A, B 152A,B 255A,B 156A, B 257A,B 158A,B 259A,B 163A,B 264A,B 1 and 262A,B 162A,B 161A,B 161A,B 165A,B 167A,B 169A,B 169A,B 168A,B; 67A,B 171A,B 166A,B 173A,B 173A,B 174A,B 1 and 256A,B & 1 and 257A,B(Torus Room Only)PROTECTEDSAFE SHUTDOWNSHT # PATHPREFIRE PLANDWG #TURBINE BUILDINGEAST CABLEWAYTURBINE BUILDINGWEST CABLEWAYTURBINE DECKSTAIRWAYSEAST CABLEWAY FOYERA-43965A-43965A-43965A-43965A-43965A-4396534A,BN/A81A,B87A,B, 88A, BN/A34A, B122222 V20Page 7 of 20SNC LAN E.I. HTCHI IPg 90 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 3_ Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 1 1 OF 81.0 PATHWAY 1 TO SHUTDOWNSystems Required1.1.1 RHR, Pump A; RHR Service Water Pump A.1.1.2 RClC1.1.3 SRVs, Gand H1.1.4 Plant Service Water, Pump A1.1.5 RHR and RClC Emergency Room Ventilation System, A Coolers1.1.6 RPV Instrumentation1.1.7 Containment Instrumentation1.1.8 Drywell Air Supply1.1.9 Diesel Generator and Associated Electrical Equipment1.1.10 MSIVs1.1.11 Diesel Building Ventilation1.1.12 Intake Structure Ventilation V20Page 8 of 20SNC LAN E.I. HTCHI lPg 98 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001 -1 13.1ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 2 1 OF 82.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR System, Pump B; RHR Service Water Pump B.2.2.2 RHR and HPCI Room Coolers, B Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air2.2.7 Diesel Generator and Associated Electrical Equipment2.2.8 HPCI2.2.9 Core Spray (for Fire Area 1203 only)2.2.10 SRVs, A and C.2.2.11 MSIVs2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 9 of 20SNC LANTE. I HATH IPg 106 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 3 I OF 83.0 PATHWAY 3 TO SHUTDOWN3.1 Systems Required3.2.1. RHR System, Pump B; RHR Service Water Pump B3.2.2. RHR and RCIC Room Coolers3.2.3. Plant Service Water, Pumps A and B.3.2.4. RPV Instrumentation3.2.5. Containment Instrumentation3.2.6. Drywell Air3.2.7. Diesel Generator and Associated Electrical Equipment3.2.8. RCIC3.2.9. SRVs, C and G.3.2.10. MSIVs3.2.11. Diesel Building Ventilation3.2.12. Intake Structure Ventilation V20Page 10 of 20SOUTERNNUCEAR I DOUMET TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 114DOCUENTTITL: IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-00 1-2 15.0EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 3-18-15 DATE:N/A SS M/PM N/A DATE N/A 3-18-2015TABLE OF CONTENTSSection Page1.0 CONDITIONS..................................................................................... 32.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.1 Control Building Ventilation Fans............................................................ 75.2 Ventilation Restoration....................................................................... 75.3 Control Building Specific Area Actions...................................................... 85.4 Oil Storage Tank Room ...................................................................... 85.5 Station Battery Rooms (FA 2005) ........................................................... 85.6 RPS Battery Rooms.......................................................................... 85.7 130 ft elev. Passageways, HVAC Room and Lab .......................................... 85.8 Annunciator Room ........................................................................... 95.9 Oil Conditioner Room (FA 2023) ............................................................ 95.10 RPS MG Set Room and Vertical Cableway................................................. 95.11 DC Switchgear Rooms....................................................................... 95.12 Switchgear Access Hallway & 600V Switchgear Room 2C............................... 105.13 600V Switchgear Room 2D................................................................. 115.14 Transformer Room 2CD .................................................................... 125.15 Main Control Room, Cable Spreading Room or Computer Room ....................... 135.16 Control Building 112 ft Elevation Working Floor, Corridor, and Annunciator Logic Cabinet(FA 0001).................................................................................... 145.17 Water Analysis Room (FA 2006)........................................................... 146.0 DIESEL GENERATOR BUILDING............................................................. 156.1 Diesel generator Building Specific Area Index ............................................ 156.2 DG Battery Rooms.......................................................................... 156.3 DG Day Tank Rooms ....................................................................... 166.4 DG Engine Rooms.......................................................................... 186.5 DG 2A Swgr Room 2E (2R22-S005) ...................................................... 196.6 DG 1B Swgr Room 2F (2R22-S006) ...................................................... 206.7 DG 2C Swgr Room 2G (2R22-S007) ...................................................... 217.0 YARD ............................................................................................ 227.1 Plant Yard Specific Area Index............................................................. 227.2 Intake Structure ............................................................................. 227.3 Nitrogen Storage Tank AREA.............................................................. 23 V20Page 11 of 20PAGE2 OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.07.4 Main or Unit Auxiliary Transformer......................................................... 237.5 Startup Auxiliary Transformer .............................................................. 237.6 Auxiliary Boiler .............................................................................. 237.7 Waste Gas Treatment Building....................,......................................... 237.8 High Voltage Switchyard ................................................................... 237.9 Circulating Water Pump Pit ................................................................ 238.0 REACTOR BUILDING .......................................................................... 248.1 Reactor Building Ventilation................................................................ 248.2 Reactor Building Specific Area Index...................................................... 248.3 North Half of Reactor Building Below 185 ft ............................................... 258.4 ASD Rooms ................................................................................. 278.5 South Half of Reactor Building, and All of the 185 ft and 203 ft Elevations ............. 288.6 Drywell....................................................................................... 389.0 TURBINE BUILDING ........................................................................... 399.1 Turbine Building Specific Area Index ...................................................... 399.2 Turbine Building............................................................................. 399.3 Turbine Building Unit 2 East Cableway (2104)............................................ 409.4 Turbine Building East Cableway Foyer .................................................... 409.5 Turbine Building Unit 1 East Cableway.................................................... 4110.0 RADWASTE BUILDING ....................................................................... 4210.1 Ventilation Charcoal Filter trains ........................................................... 4211.0 RECORDS ..................................................................................... 4312.0 COMMITMENTS............................................................................... 43Attachments1 SAFE SHUTDOWN ACTIONS ................................................................. 442 PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 ................................ 853 SAFE SHUTDOWN PATHS FOR UNIT 2 FOR UNIT 1 FIRES .............................. 894 SAFE SHUTDOWN COMPONENT LIST PATH 1I............................................ 905 SAFE SHUTDOWN COMPONENT LIST PATH 2 ............................................ 966 SAFE SHUTDOWN COMPONENT LIST PATH 3 ........................................... 1037 LINKS NORMALLY OPEN TO SUPPORT APPENDIX R ................................... 1108 REFERENCE DRAWINGS LIST.............................................................. 1119 PLACARDS FOR 2H11-P601................................................................. 11310 KEY MILESTONES FORA FIRE OR FIRE DRILL .......................................... 114 V20Page 12 of 20SOUTERN UCLER IPAGEPLAN E. .HACHJ250OF 114DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.08.3 NORTH HALF OF REACTOR BUILDING BELOW 185 FT. ELEVATION8.3.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.3. LII8.3.2 This fire area consists of the following fire zones, perform the steps applicable to the area:STEP ZONE PAGE8.3.3 North Half of Torus Room ............................................................ 258.3.4 RCIC Corner Room ................................................................... 258.3.5 Div I RHR and Core Spray Corner Room............................................ 268.3.6 130 Ft Elevation, North Half.......................................................... 26Reactor Building Stairwell NO ACTIONS *158 Ft Elevation, North Half NO ACTIONS ** No additional actions are required beyond normal fire response actions.8.3.3 North Half of Torus Room8.3.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. Eli8.3.4 RClC Corner Room8.3.4.1 Stop RClC Pump Rm Coolers.* 2T41-B004A El* 2T41-B004B El8.3.4.2 Close RClC Steam Supply Isol AND Steam Supply Line Isol Valves.* 2E51-F007 El* 2E51-F008 El V20Page 13 of 20PAGE280OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-2 15.08.5 SOUTH HALF OF REACTOR BUILDING, AND ALL OF THE 185 FT AND 203 FTELEVATIONS8.5.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.5. LI8.5.2 This fire area consists of the following fire zones,perform the steps applicable to the fire zone: LISTEP ZONE PAGE8.5.3 South Half of Torus Room........... ............................................... 278.5.4 CRD Corner Room.................................................................. 288.5.5 Div II RHR and Core Spray Corner Room (Southeast) ........................... 298.5.6 HPCI Room.......................................................................... 298.5.7 130 Ft Elevation, South Half........................................................ 308.5.8 158 Ft. Elevation South Half........................................................ 308.5.9 164 Ft HVAC Room................................................................. 318.5.10 Fuel Pool Cooling And Heat Exchanger Room.................................... 328.5.11 Fuel Pool and RWCU Precoat Equipment Area................................... 328.5.12 185 Ft Elevation Working Floor .................................................... 338.5.13 185 Ft HVAC Room................................................................. 348.5.14 Standby Gas Treatment Room..................................................... 348.5.15 203 Ft Working Floor................................................................ 358.5.16 203 Ft HVAC Room................................................................. 358.5.3 South Half of Torus Room8.5.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. L[]

V20Page 14 of 20SNC LAN E.I. HTCHI I Pg 85 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 1 OF 4*The Safe Shutdown Paths listed indicate the Safe Shutdown Train that has been analyzed for a firein the associated area. The Safe Shutdown Path (1 OR 2) least impacted by the fire in each areawas identified AND analyzed. It is assumed that only one path is available for shutdown for thepurpose of engineering analysis. This does NOT prevent Operator use of systems outside of theanalyzed path IFE they continue to function as required. For fire areas where protection of one pathCANNOT be achieved, such as the Main Control Room, Cable Spreading Room AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND~. analyzed.* Where circuit failures to analyzed path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are analyzed WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 4 (Path 1), Attachment 5 (Path 2) AND Attachment 6 (Path 3 -RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, may survive the fire. Circuit faults to unanalyzed equipmenthave NOT been evaluated.

V20Page 15 of 20SNC LANTE. I HATH IPg 86 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 2 OF 4ANALYZEDPREFIRE PLAN SAFE SHUTDOWNCONTROL BUILDING DWG # SliT# PATH112 Ft Elev Passageways, Hot Instrument Shop A-43965 5A, B 2and Service Air Compressor RoomsOil Storage Tank Room A-43965 1 6A, B 1 and 2Freight Elevator or Stairway A-43965 6A, B 2Station Battery Room 2A A-43965 1 7A, B 2Station Battery Room 2B A-43965 1 8A, B 1AC Inverter Room A-43965 20A, B 1 and 2RPS Battery Room 2A A-43965 21A, B 1 and 2RPS Battery Room 2B A-43965 22A, B 1 and 2Water Analysis Room A-43965 1 9A, B 1Unit 2 130 Ft Elev Switchgear Hallway A-43965 24A, B 2Switchgear Hallway Enclosure A-43965 35A, B 2All Other 130 Ft Elev Passageways A-43965 24A, B 2HVAC Room -130 Ft Elev A-43965 25A, B 2RPS MG Room A-43965 26A, B 1Vertical Cable Chase A-43965 26A, B 2Annunciator Room A-43965 36A, B 2Oil Conditioner Room A-43965 42A, B 2DC SWGR Room 2A A-43965 39A, B 2DC SWGR Room 2B A-43965 41A, B 1Rad Protection Area and Radwaste Lab A-43965 23A, B 2600V SWGR Room 2C A-43965 37A, B 2I600OV SWGR Room 2D A-43965 38A, B 12CD Transformer Room A-43965 40A, B 1CO2 Storage Tank Area A-43965 46A, B 2LPCI Inverter Room A-43965 47A, B 2Main Control Room A-43965 48A, B 3Cable Spreading Room A-43965 44A, B 3Computer Room A-43965 45A, B 3Control Room Roof A-43965 50A, B 2Control Bldg East Corridor, Cold Lab, and A-43965 7A, B 2Adjacent Rooms, El 112 9A, BSwitchgear Access Hallway A-43965 35A, B 1 V20Page 16 of 20SNC LANTE. I HATH IPg 87 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 3 OF 4DIESEL GENERATOR BUILDINGDG Building HallwayDG 2A Battery RoomDG 1 B Battery RoomDG 2C Battery RoomDG 2A Day Tank RoomDG 1 B Day Tank RoomDG 2C Day Tank RoomDG 2A Engine RoomDG 1B Engine RoomDG 2C Engine RoomDG 2A SWGR Room 2EDG lB SWGR Room 2FDG 2C SWGR Room 2GPREFIRE PLANDWG #A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SliT#5A, B19A, B11A, B23A, B18A, B10A, B22A, B20A, B12A, B24A, B21A, B25A, B26A, BANALYZEDSAFE SHUTDOWNPATH1 and 221 and 2121 and 2121 and 21221YARDCooling TowersIntake StructurePlant Service Water Valve Pit 2APlant Service Water Valve Pit 2BCondensate Storage Tank AreaNitrogen Storage Tank Area500KV Reactor SwitchyardMain 500 KV SwitchyardAuxiliary BoilerCirc Water Pump PITRadwaste Dilution Valve PitDiesel 2A Fuel Oil Storage TankDiesel 20 Fuel Oil Storage TankA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396677A, B79A, B, C, D27A, B50A, B51A, B44A, B42A, B84A, B82A, B61A, B53A, B59A, B73A, B73A, B1 and 21 and 22121 and 21 and 22N/A2221 V20Page 17 of 20SNC LAN E.I. HTCHI IPg 88 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-00 1-2 J 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 J 4 OF 4PREFIRE PLANDWG #ANALYZEDSAFE SHUTDOWNPATHREACTOR BUILDINGSHT#Div I RHR and Core Spray NE Corner RoomDiv II RHR and Core Spray SE Corner RoomCRD Corner RoomRClC RoomHPCI RoomTorus Room -South HalfTorus Room -North Half130 Ft Elev -South130 Ft Elev -NorthRecirc ASD Room 2ARecirc ASD Room 2BRWCU Pump A RoomRWCU Pump B Room158 Elev South -Working Floor158 Elev North164 Ft Elev HVAC RoomFuel Pool Cooling Heat ExchangerFuel Pool and RWCU Precoat Equip Area185 Ft Supply Fan Room185 Ft Working Floor185 Ft HVAC RoomSBGT Room ASBGT Room B203 Ft Elevation203 Ft ElevationRefuel FloorDrywellA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-4396599A, B 2101AB 1102AB 1100A.,B 2103A.,B 1105A. B 1104AB 2107AB 1106A, B 2113A, B 1land 2114A, B 1land 2111A, B 1111A, B 1110A, B 1109A, B 2112A, B 1116A, B 1116A, B 1118A, B 1116A, B117A,B 1118AB 1115A, B 1115A, B 1122A, B 1120A,B 121A,B 1123A, B 1land 2104A,B 105A,B 1 and 2(Torus Area Only)108A, B 1Main Steam ChaseTURBINE BUILDINGTurbine Bldg Fire Area 2101164 Ft Elev Turbine Deckand other Fire Area 0101Turbine Building Below Turbine DeckWest CablewayStairwaysTurbine DeckEast CablewayA-43965A-4396549A, B 87-90A, BA-43965A-43965A-43965A-43965A-43965124-1 32A,133-1 36A,N/A128A, BN/A134A, B43A, BBB2122221 V20Page 18 of 20SNC LANTE. I HATH 1Pg 90 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001-2 15.0ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 1 1 OF 61.0 PATHWAY I TO SHUTDOWN1.1 Systems Required1.2.1 RHR, Pump A, RHR Service Water Pump A1.2.2 RCIC1.2.3 SRVs1.2.4 Plant Service Water, Pump A1.2.5 Emergency Room Coolers1.2.6 RPV Instrumentation1.2.7 Containment Instrumentation1.2.8 Drywell Air (Nitrogen System, Drywell Pneumatic System)1.2.9 Diesel Generator 2A and Associated Electrical Equipment1.2.10 MSIVs, Inboard1.2.11 Core Spray Loop A (for spurious ADS WHEN RHR Loop "A" NOT available)1.2.12 Diesel Building Ventilation1.2.13 Intake Structure Ventilation1.2 System Components1.2.1 RHR, Pump A and RHR Service Water, Pump ARequiredNormal PATH 1MPL No Mode SSD Mode2E11-C001A OFF ON2E11-C002A OFF ON2E11-F003A 0 02E 11-F004A 0 02E11-F006A C C2E11-F007A 0 VAR2E1l-F010 C C2E11-F011A C C2E11-F015A C 02E11-F016A C C2E11-F017A 0 02E11-F026A C C2E11-F028A C C2E11-F047A 0 02E11-F048A 0 VAR2E11-F065A 0 0RequiredNormal PATH 1MPL No Mod._._e SSD Mode2E11-F068A C VAR2E11-F073A C C2E1 1-F104A C C2E11-F119A C C2E11-K600A ON ON2E11-K603A ON ON2E11-N007A ON ON2E11-N015A ON ON2E11-N017A C 02E11-N017C C 02E11-N082A ON ON2E11-N104A ON ON2E11-N682A C VAR2E11-R600A ON ON2E11-R602A ON ON2E11-R603A ON ON V20Page 19 of 20SNC LANTE. I HATH IPg 96 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 2 I OF 72.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR, Pump B, RHR Service Water Pump B2.2.2 Emergency Room Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)2.2.7 HPCI2.2.8 Diesel Generator 2C and Associated Electrical Equipment2.2.9 Core Spray, Loop B (for spurious ADS WHEN RHR Loop "B" NOT[ available)2.2.10 SRVs2.2.11 MSIVs, Outboard2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 20 of 20SNC LANTE. I HATH IPg 103 of 114DOCMET ITE:DOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 6 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 3 1OF 73.0 PATHWAY 3 TO SHUTDOWN (REMOTE SHUTDOWN SYSTEMS)3.1 Systems Required3.2.1 RHR, Pump B, RHR Service Water Pump B3.2.2 Emergency Room Coolers3.2.3 Plant Service Water, Pump B3.2.4 RPV Instrumentation3.2.5 Containment Instrumentation3.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)3.2.7 RCIC3.2.8 Diesel Generators 2A and 2C and Associated Electrical Equipment3.2.9 SRVs3.2.10 MSIVs, Inboard3.2.11 Diesel Building Ventilation3.2.12 Intake Structure Ventilation V21Page 1 of 14. ITheMinmumSteam Cooling RPV Water Level for Hatch is: -180 inches. (Both5. The Minimum Steam Cooling RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. The temperature of the water injected into the RPV is 1 000F.6. Plant-specific data required to calculate the Minimum Steam Cooling RPV WaterLevel is as follows:a. Minimum active fuel length fraction which must be covered to maintain peakclad temperature below 1 5000F with injection.b. Active fuel lengthc. Water level at the bottom of the active fuelE. Minimum Zero-Injection RPV Water Level(LT 31) (LCT 31)1. The Minimum Zero-Injection RPV Water Level is defined to be the lowest RPVwater level at which the covered portion of the Reactor core will generate sufficientsteam to preclude any clad temperature in the uncovered portion of the core formexceeding 1 8000F. This Water Level is utilized to preclude significant fuel damageand hydrogen generation for as long as possible.2. This is the level at which Steam Cooling Without injection is used in the EOPs.A cold shutdown rod configuration must exist to use this core cooling method.3. The Minimum Zero-Injection RPV Water Level for Hatch is: -195 inches.(Both units)4. The Minimum Zero-Injection RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. No water is injected into the RPV.EOP-CURVES-LP-20306 Ver 3.0 GRAPH 2V22Page 1 of 2UNIT 1HEAT CAPACITY TEMPERATURE LIMIT0[-(i-TORUS WATER LEVEL (in)NOTE: May use SPDS Emergency Displays in place of this Graph.* Safe operating is below the applicable pressure line.

V22Page 2 of 2SGRAPH 2Heat Capacity Temperature LimitEI-2602402202O00180160140120._'C')I..'IC')0Ra-x.I8098 120 140 160 180193200Torus Water Level (in)Note: May use SPDS in place of this GraphREQUIRED if above curve for existing RPV pressEOP-CURVES-20306FIG 2Page 61 of 75 V23Page 1 of 4Mare Condenser Offgas3.7.63.7 PLANT SYSTEMS3.7.6 Main Condenser OffgasLCO 3.7.6tiT e gross gamma actvity rate of the noble gases measured at the maincondenser evacuation system pretreatmentl monitor station shall be240 mCi/seond. ,MODE 1,MODES 2 and 3 with any main steam line not isolated and steam jet airejector (SJAE) in operation.APPLICABILITY:ACTIONS___________ _____ ___CONDITION REOUIRED ACTION COMPL=ETION TIMEA. Gross gamma activity rate A.1 Restore gross gamma 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months sof the noble gases not activity rate of the noblewithin limit, gases to limit.B8 Required Action and B. 1 Isolate all main steam 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sassociated Completion linesTime not met.OR8.2 Isolate SJAE 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sORRB.3.1 Be in MODE 3 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sANDB,3.2 Be in MODE 4. 36 hootsHATCH UNIT 23.7-16HATC UNI 2 37-16Amendment No. 135 CDCD0(0CDN, 0-9CD V23, Page 4 of 4SU3 Reactor coolant activity greater than Technical Specification allowable limits.Operating Mode:Power OperationStartupHot StandbyHot Shutdown(1 OR 2)Emergency Action Levels:1. Pretreatment Radiation Monitor reading greater than 240,000 pCi/sec for greater than60 minutes.According to Tech. Spec. Bases 3. 7.6 page B3. 7-31 and Tech. Spec. section 3. 7.6page 3. 7-16, the gross gamma activity rate of the noble gases measured at the maincondenser evacuation system pretreatment monitor station shall be <.240mCi/secondor <240, O00pCifsecond. According to 64C1-0CB-006-1/2 procedures the offgaspretreatment radiation monitors are 1/2D1 1-K601 and 1/2D1 1-K602OR2. Sample analysis indicates that the reactor coolant specific activity is EITHER:* Greater than 0.2 pCi/gm and less than or equal to 2.0 pCi/gm doseequivalent 1131 for greater than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .* Greater than 2.0 pCi/gm dose equivalent 1131.According to Tech. Spec. Bases 3. 4.6 page B3.4-25 and Tech. Spec. section 3. 4.6page 3.4-11, the specific activity of the reactor coolant shall be limited to DOSEEQUIVALENT 1-131 specific activity 0.2 IJCi/gm. A condition >0.2 pCi/gm but <2.OIJCi/gm must be restored within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . A condition > 2pCi/gm requires immediateaction, V24Page 1 of 1RCS Specifi Activity3.4.63.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 RCS Specific ActivityLCO 3.4.6Thre specifi activty of the reactor coolant shag be limited to DOSEEQUIVALEFNT 1-131 speific activit 0.2 pC~igm.APUCBIUTrY:MODE 1,MODS 2 and 3 with any m'aui steam line not isolated.ACTIONSCO,,NDmON REQUIRED ACTION COMPLETION TIMEA.Reacto colaspecifi NOTESacbvtty 0.2 &aCim and LCO 3.0.4.c is apl:iicable.1 2.0 DOSElEQUIVALENT 1-131.A.1 Determine DOSE Once per 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months sEQUIVALENT 1-131.ANDA.2 Restore DOSEEQUIALENT 1-131 toB. Required Ac~tion an B.1 Determine DOSE Once per 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months sassociated Completion EQUIVALENT 1-131.Time of Cocst A notQR B2.1 Isolate all main steam 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sReactor coolant spciiactivity >2.0 DOSE OEQUIVALENT 1-131.B22.1 BeminMODE 3. 12 IurS8222 Be in MODE 4. 36 hour4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months sHATCH UNIT 23.4-11HATH UIT 34-1 AmndmntNo. 210 V25Page 1 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (Refs. 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation and thecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 1 .-3RVSOB 3.4-13REVISION 0 V25Page 2 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment canI(continued)HATCH UNIT 1 B341 EIIN5B 3.4-14REVISION 59 V25Page 3 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._IWith RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 1 .-5RVSOB 3.4-15REVISION 0 V25Page 4 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (References 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation andthecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 2 B341 EIIN7B 3.4-14REVISION 77 I V25Page 5 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment can(continued)HATCH UNIT 2 B341 EIIN7B 3.4-15REVISION 77 I V25Page 6 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in' anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._1!With RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 28341REION7B 3.4-16REVISION 77

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HATCHPAGE 9 OF 30DOUMNTTILE t DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL t 34AB-T22-003-1 5.14ATTACHMENT 2 ATT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1G31-R604) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1H11-P614, 1G31-R604 Value Value0F o158' ELEVATION AREA (RWCU)101 B Pump Room (1G31-N016D) 150 212.5102 B Pump Room DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Room (1G31-N016B) 150 212.5104 Hx Room DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B (1E11-N009B) 150 212.5108 RHR/CS B DIFF(1E11-N030B/1E11-N029B) 40 98HPCl ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245110 HPCI VENT AIR DIFF (1E41-N029B/1E41-N028B) NA NA(not used)RCIC ROOM AREA111 Emer Area CIr (1 E5I-N023B) 167.5 310112 RCIC VENT AIR DIFF (1E51-N022B/1E51-N021 B) NA NA(not used)TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1E51-N025D) 167.5 212.5115 VENT AIR DIFF (1E51-N027B/1E51-N026B) 42 102116 VENT AIR DIFF (1 E51-N027D/1 E51-N026D) 42 102HPCI PIPE PENETRATION ROOM117 1E41-N046B 150 212.5Posted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 2 of 10PAGE 10 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 3 ATTACH. PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1 G31 -R608) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1IH11-P614, 1G31-R608 Value ValueoF o158' ELEVATION AREA (RWGU)101 A Pump Room (1G31-N016C) 150 212.5102 A Pump Room DIFF (1G31-N022B/1G31-N023B) 67 98103 Hx Room (1G31-N016E) 150 212.5104 Hx Room DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF (1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A (lE1 1-N009A) 150 212.5108 RHRICS A DIFF (1EI11-N030A/1 E11-N029A) 40 98HPCI ROOM AREA109 Pump Room (1E41-N024) 167.5 245110 Emer Area CIr (1 E41 -N030A) 167.5 245111 HPCl VENT AIR DIFF (1 E41-N029A/11E41-N028A) NA NA(not used)_________RClC ROOM AREA112 Pump Room (1E51-N011) 167.5 310113 Emer Area CIr (1E51-N023A) 167.5 310114 RCIC VENT AIR DIFF (1 E51-N022A/1 E51-N021A) NA NA(not used)TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-N025C) 167.5 212.5117 VENT AIR DIFF (1 E51-NO26AI1 E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1 E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm TnI 1B21-N014 192.5 300120 1B21-N016AN0O16B DIFF 60 150HPCI PIPE PENETRATION ROOM 150 212.5121 1E41-N046APosted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 3 of 10PAGE 27 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE ]DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2Max MaxSECONDARY CONTAINMENT TEMPNoml Sfon IHI1-P614, 1G31-R604 0158' ELEVATION AREA (RWCU)101 B Pump Rm (1G31-N016D) 150 212.5102 B Pump Rm DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Rm (1G31-N016B) 150 212.5104 Hx Rm DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B(1E11-N009B) 150 212.5108 RHR/CS B DIFF (1E11-N030B/1E11-N029B) 40 98HPCI ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245RCIC ROOM AREA111 Emer Area Clr (1 E51-N023B) 167.5 310TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1 E51-N025D) 167.5 212.5115 Vent Air DIFF (1E51-N027B/1E51-N026B) 42 102116 Vent Air DIFF (1E51-N027D/1E51-N026D) 42 102HPCl PIPE PENETRATION ROOM117 1E41-N046B 150 212.5RDG RDG1 23Reference 34AB-T22-003- 1MGR-0009 Rev 5.0 Vi18Page 4 of 10PAGE 28 OF 30SOUTHERN NUCLEARIPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT -9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP Max Maxon 1H11-P614, 1G31-R608 Normal Safe158' ELEVATION AREA (RWCU)101 A Pump Rm (1G31-N016C) 150 212102 A Pump Rm DIFF (1G31-N022BI1E51-N023B) 67 98103 Hx Rm (1G31-N016E) 150 212.5104 Hx Rm DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF(1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A(1E11-N009A) 150 212.5108 RHR/CS A DIFF (1E11-N030A/1E11-N029A) 40 98HPCl ROOM AREA109 Pump Rm (1E41-N024) 167.5 245110 EmerArea Clr(1E41-N030A) 167.5 245RCIC ROOM AREA112 Pump Rm (1E51-N011) 167.5 310113 EmerArea CIr (1E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-NO25C) 167.5 212.5117 VENT AIR DIFF (1E51-N026A11E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm Tnl (1B21-N014) 192.5 300120 1B21-N016A/N016B DIFF 60 150HPCI PIPE PENETRATION ROOM121 1E41-N046A 150 212.5I/RDG RDG RDG1 2 3I________Iec 4B-2-0-MGR-0009 Rev 5.0 V18Page 5 of 10PAGE 29 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL 34AB-T22-003-1 5.14ATTACHMENT 10 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT PARAMETERS 1 OF 1Imax 14" aow8rTelw.Ir Irt' 3TabowSTe~ev.t#' aovSe lteev.DIAGONALAREA150212.5I.IV ROOMAIEA wI' h svIo"fl vi" IT 71e,CO4hNMENREFA RADIATIONIMONITORS I [g~11.SS 1211UV~jteVaeIEREL FLO(F AREA1Reathe.J iee (1D21-KG00A) 50 10002 a u(IO141-01 B) 50 10(003 P.uuI o(1O21-K60lD) 50 10004 Dr~weIl 50 10005 SpeltFtmlPool&New~uelStcrage(1D21.K501M 50 10005RB20Wor~ru(1D21K0 X) 50 7 SpentFuel PoC DeuinvEquip{1O21.01C) 150 I1Q000eFu.PocDsrmin, Pmn(1D21.K17) 50 10 ___9 R81irWokArea(1D214K601K) 50 1 00010 RxbSarjiRzdkue (ID214K601L) 50 1 000)11 50 IOQ0012 NothCRVHCU(1021-IQD1P) 50 I100014 R8130N.E~odinku(1D21.K601G) 50 I100015 50 ]1000 __ELEVATION SOUTH AREA16 50 100017 SoutthCAOHCJ(1D2FH(0tN) 50 1000 _18 RCCEEupSWDmgna(1O21.KO1V) 50 I1000NORfN"TI~LAOA AREA19 CR)PumpiWOIagvnI(1D21.(801W) 50 I1000NOfES G4LAREA20 CS&RJIRN~.Edg(1D21-KIE01Y) 50 1000SOUT~fJST ENA-(NAL ARE --_ -21 CS&Rk-IlS,,EDigoza{IDT2.K6O1R) 50 1 (000!J7 ELEVATION AREA ET22 HFOTuwtmieAlui1D214t01T) 150 I10(001OP114S-~1933~I l=l 1I34AB-T22-O03-1OPS-1 933MGR-0009 Rev 5.0 V1 8Page 6 of 10PAGE 9 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 2 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 1(2G31-R604)_________MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H11-P614, OPERATING OPERATING2G31-R604 VALUE VALUE&deg;F &deg;F158' ELEVATION AREA (RWCU)101. B pump room (2G31-N016B) 150 215102. B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103. Hx Room (2G31-N016D) 150 215104. Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105. Valve Nest (2G31-N016F) 150 215106. Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 99SOUTHEAST DIAGONAL AREA107. RHR/CS B (2E11-N009B) 150 190108. RHR/CS B DIFF (2E11-N030B/2E11-N029B) 40 74HPCI ROOM AREA109. Emer area clr (2E41-N030B) 167.5 245110. HPCl vent air DIFF (2E41-N029B/2E41-N028B) NA NA(not used)______ ____RClC ROOM AREA111. Emer Area CIr (2E51-N023B) 167.5 310112. RCIC vent air DIFF (2E51-N022B/2E51-N021B) NA NA(not used)______ ____TORUS ROOM AREA113. Northwest Wall (2E51-N025B) 167.5 212.5114. Southeast Wall (2E51-N025D) 167.5 212.5115. Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116. Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117. 2E41-N046B 167.5 212.5 Vi18Page 7 of 10PAGE 10 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 3 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (2G31 -R608) 1 OF 1MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H1 1-P614, OPERATING OPERATING2G31-R608 VALUE VALUE&deg;F &deg;F158' ELEVATION AREA (RWCU)101. A Pump Room (2G31-N016A) 150 215102. A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 99103. Hx Room (2G31-N016C) 150 215104. Hx Room DIFF (2G31-N023C/2G31-N022C) 67 99105. Phase Sep Rm (2G31-N016E) 150 215106. Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 99NORTHEAST DIAGONAL AREA107. RHR/CS A (2E1 1-N009A) 150 215108. RHR/CS A DIFF (2E11-N030AN2E11-N029A) 40 74HPCI ROOM AREA109. Pump Rm (2E41-N024) 167.5 245110. Emer Area CIr (2E41-N03OA) 167.5 245111. HPCI Vent Air DIFF (2E41-N029A/2E41-N028A) NA NA(not used)__________RCIC ROOM AREA112. Pump Rm (2E51-N011) 167.5 310113. Emer Area CIr (2E51-N023A) 167.5 310114. RCIC Vent Air DIFF (2E51-N022A12E51-N021A) NA NA(not used)TORUS ROOM AREA115. West Wall (2E51-N025A) 167.5 212.5116. Northeast Wall (2E51-N025C) 167.5 212.5117. Torus Vent Air DIFF (2E51-N027A/2E51-N026A) 42 98118. Torus Vent Air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119. Main Steam Tunnel (2B21-N014) 192.5 310120. Main Stm Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150HPCI PIPE PENETRATION ROOM121. 2E41 -N046A 167.5 212.5 V18Page 8 of 10PAGE 30 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT _9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2SECONDARY CONTAINMENT TEMPMMAon 2H11-P614, 2G31-R604 NORMALj SAFE158' ELEVATION AREA (RWCU)101 B pump room (2G31-N016B) 150 215102 B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103 Hx Room (2G31-NO16D) 150 215104 Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105 Valve Nest (2G31-N016F) 150 215106 Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 9SOUTHEAST DIAGONAL AREA107 RHR/CS B (2E11-N009B) 150 J190108 RHR/CS B DIFF (2E1 1-N030B/2G31-N029B) 40 J 74HPCI ROOM AREA109 Emer Area CIr (2E41-N030B) I67.5 245RCIC ROOM AREA111 Emer Area CIr (2E51-N023B) 16. 1TORUS ROOM AREA113 Northwest Wall (2E51-N025B) 167.5 212.5114 Southeast Wall (2E51-N025D) 167.5 212.5115 Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116 Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117 2E41-N046B Ii7.5I 212.5Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 SOUTHERN NUCLEARPLANT E.I. HATCHVi18Page 9 of 10PAGE 31 OF 37DOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP MAX MAXon 2H11-P614, 2G31-R608 NORMAL[ SAFE158' ELEVATION AREA (RWCU)101 A Pump Room (2G31-N016A) 150 21102 A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 9103 Hx Room (2G31-N016C) 150 21104 Hx Room DIFF (2G31-N023C/2G31-N022C) 67 9105 Phase Sep Rm (2G31-N016E) 150 21106 Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 9NORTHEAST DIAGONAL AREA107 RHR/CS A (2E1 1-N009A) 150 21108 RHR/CS A DIFF (2E11-N030AI2E11-N029A) 40 174HPCl ROOM AREA109 Pump Rm (2E41-N024) 167.5 245110 Emer Area Clr(2E41-N030A) 167.5/ 245RClC ROOM AREA112_Pump Rm_(2E51-N011) 167.5 _310113 Emer Area Clr (2E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (2E51-N025A) 167.5 212.5116 Northeast Wall (2E51-N025C) 167.5 212.5117 Torus vent air DIFF (2E51-N027A12E51-N026A) 42 98118 Torus vent air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119 Main Steam Tunnel (2B21-N014) 192.5 310120 Main Steam Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150RDG RDG1 RDG1 2 3-B_HPCl PIPE PENETRATION ROOMI121 2E41,N046A [167.5 212.5_Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 V1 8Page 1 0 of 10PAGE 35 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 1"1 ATTACHMENT PAGE:TITLE: SECONDARY CONTAI NMENT PARAMETERS 1 OF 1Table 4 o'9tA~hG~iWAfliI I C0NbleN 5 A101102AREA WATER LEVELSMax NanulMaxSafe.___ 4" r/5T'sia 33 isv .1.AREA4"iow ST ealeion!$"o8T 1ev'.4icvelTelwian 27.bovel7'elw.diov.STal.vglwit#' above $'t' 4" isve 8'uleiion14" isy rr sh,4 aov 57' ekydontt" above 37' .ev.Table 6 ARIA MOR10.3yaw awS UUHd113 l 51-N058) I167.5 212.5114 Sou WlbeI (2E514NU50) l167.5 212.5116 ToqusM VtOIFF 42 901 A Pw~own%2;G31.#408Ao mpRoooN2G314 t3Phu Sep Rm(2m1.N01E)Va15067'so57150RiVa21599215982151 Reac had (2D21-K601A) 50 1Q0003 SfouIlo&NswFu l~g.(2f21.KBO1M) 50 10004 ahFboor(2D214(SI11K) 5o 10o0G Reeor Vesse!RFloor (2Q21.K811 L) 50 1Q00063 (2D214,SO1T) 50 10]007 HV o&#xa2;W 50 1008 Spn u olPsaea 50 10009 RB 18 qelegIoor(2O21..KO0R) 50 100010 R81W Samispuue t.lme(221.(8O1S) 50 1Q000I'I R818 cou~rol pa-.(2O21-K601U) 15O t000__13 S reaIW (2D21.(501D) 50 1000__15Dean um eupmntronara 50 1000__`10001307 ELEVATION ARE.A (NSRUThWSN(R11PMB(2T2IMOIF) L AO RtOA217 50 .100022 RC1S.W4~odgAii(2D21,,K601X) 50 .100023 cs&rRls~dagoi(2V214WO1Y) 150 1000O115 16+7.5 21 21542 198l34AB-.T22-003-2OPS-1932OPS-1 932 V19Page 1 of 4PAGE 2 OF 3SOUTHERN NUCLEARPLANT E.I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:ARP'S FOR CONTROL PANEL 2H1 1-P657, 34AR-657-901-2 I 23.1ALARM PANEL 1UNIT 22H11-P657 -1 (LEFT)657-001 657-002 657-00.3 557-004 57-005 657-006 657-007 657-008 657-009657-019 657-020 657-021 57-02 657-023 657-024 657-025 657-026 657-027657-037 657 -03 6 57-03;; 57-040 6 7-041 657-042 657-043 657-044 657-045657-055 657-05S G57 057 657-058 -5705 657-060 657-061 657-062 657-063657-07 657-074 657-075 657-0Th 657-77 657-07 657-079 657-080 657-081657-091 57 0 2 657-093 557-094 657-095 657 096 65-097 657-098 657-0992H11-P657 -1 (RIGHT)657-010 657-011 G57-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 ss57-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 65 7-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-0B3 65-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108Level Of Use ARPsCONTINUOUS ALLREFERENCE NoneINFO None Vi19Page 2 of 41.0 IDENTIFICATION:ALARM PANEL 657__ _______SEISMIC* INSTRUMENTATIONTRIGGEREDDEVICE: SETPOINT:2L51-N022 0.08 g horizontal, 0.54 g vertical2L51 -N024 0.18 g horizontal, 0.063 vertical2.0 CONDITION: 3.0 CLASSIFICATION:[ EQUIPMENT STATUSMotion has been detected in Unit 2 Reactor Building on4.LOAINelevation 87' or 185' 4 H0 LOCATION5.0 OPERATOR ACTIONS:5.1 At Panel 1 Hi11-P701, check for further indications of a seismic eventby monitoring Peak Shock Annunciator, 1 L51-R620,for 12.7 Hz amber lights (> 0.08g, OBEY) and 12.7 Hz red lights (> 0.15g, DBE). LII5.2 Refer to Seismic Instrumentation Earthquake Response Manual, SX-18271,for guidance in analyzing seismic data. LI5.3 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. LI5.4 Enter NMP-EP-1 10, Emergency Classification Determination and Initial Action. LI5.5 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. LI6.0 CAUSES:Seismic event
+==7.0 REFERENCES==
+: 8.0 TECH. SPECS./TRMIODCMIFHA:7.1 H-16319, Seismic Measurement Equip Control TRM T3.3.6 Seismic MonitoringPanel & Instrumentation. Instrumentation7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-048-2VER 4.1MGR-0048 Ver. 5.0 Vi19Page 3 of 4UNIT 1IH11-P657 -1 (RIGHT)657-010 657-011 657-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 657-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 657-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-083 657-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108RECORDSThere are no records generated by the procedureCOMMITMENTSNONEMGR-0001 Ver. 4 V19Page 4 of 41.0 IDENTIFICATION:ALARM PANEL 657________SEISMIC PEAKSHCKRECORDERJDEVICE: SETPOINT:1 L51-Vbc-R620 Not available5.0 OPERATOR ACTIONS:5.1 At Panel 1~ H1-P701, check for further indications of a seismic event,by monitoring 1L51-Vbc-R620, Peak Shock Annunciators,for 12.7 Hz amber lights (> 0.08g, OBE) AND 12.7 Hz red lights (_? 0.15g, DBE). El5.2 IF no other indications of a seismic event are present, check the following:* Peak Shock Annunciator, 1L51-vbc-R602, plugged in on Panel 1H1 1-P701 El* BRKR 3 on 120/208V Essential AC Cab, 1R25-S065 El5.3 Refer to SX-18271, Seismic Instrumentation Earthquake Response Manual,for guidance in analyzing seismic data. El5.4 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. El5.5 Enter 73EI-EIP-001-0, Emergency Classifications and Initial Actions. El5.6 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. El6.0 CAUSES:6.1 Seismic event6.2 Power failure
+==7.0 REFERENCES==
+: 8.0 TECH. SPEC.ILCO:7.1 H-16319, Seismic Measurement Equipment Control Unit 2, TRM T3.3.6 Seismic MonitorsPanel and Instrumentation.7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-066-1IVer. 3.0MGR-0048 Ver. 5AG-MGR-75-1101 V20Page 1 of 20SOUTERN UCLAR DCUMNT TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 118DOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-1 13.1EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 8-1 1-14 DATE:N/A SSM /PM N/A DATE N/A 9-11-141.0 CONDITIONSA fire exists at Plant E. I. Hatch. This procedure provides information AND actions necessary tomitigate the consequences of fires AND to maintain an operable shutdown train following firedamage to specific areas.TABLE OF CONTENTSSection Paae2.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.4 112 FT. ELEVATION ......................................................................... 75.5 OIL STORAGE TANK ROOM ............................................................... 75.6 STATION BATTERY ROOMS ............................................................... 85.7 RPS BATTERY ROOMS..................................................................... 85.8 130 FT ELEV. PASSAGEWAYS, HVAC ROOM, HP AREA, RADWASTE LAB ......... 85.9 RPS MG SET ROOM ........................................................................ 85.10 OIL CONDITIONER ROOM ................................................................. 95.11 DC SWITCHGEAR ROOMS................................................................. 95.12 600V SWITCHGEAR ROOM iC ............................................................ 95.13 600V SWITCHGEAR ROOM 1D........................................................... 105.14 TRANSFORMER lCD ROOM ............................................................. 105.15 MAIN CONTROL ROOM, CABLE SPREADING ROOM OR COMPUTER ROOM ....115.16 CONTROL ROOM ROOF .................................................................. 135.4 112 FT. ELEVATION........................................................................ 146.0 DIESEL GENERATOR BUILDING ............................................................. 156.2 DG BATTERY ROOMS..................................................................... 156.3 DG DAY TANK ROOMS.................................................................... 166.4 DG ENGINE ROOMS ...................................................................... 176.5 DG 1A SWGR ROOM 1E (1R22-S005).................................................... 186.6 DG lB SWGR ROOM iF (1R22-S006).................................................... 196.7 DG 1C SWGR ROOM 1G (1R22-S007)................................................... 207.0 YARD ............................................................................................. 217.2 COOLING TOWER ......................................................................... 227.3 INTAKE STRUCTURE...................................................................... 227.4 CONDENSATE STORAGE TANK AREA ................................................. 227.5 NITROGEN STORAGE TANK AREA...................................................... 23 SOUTHERN NUCLEARPLANT E. I. HATCHIV20Page 2 of 20PAGE2 OF 118DOCMEN TTLE IDOCUMENT NUMBER: IVERS ION NO:FI RE PROCEDURE 34AB-X43-001-.1 j 13.17.6 MAIN OR UNIT AUXILIARY TRANSFORMER............................................ 237.7 STARTUP AUXILIARY TRANSFORMER................................................. 237.8 AUXILIARY BOILER........................................................................ 237.9 COOLING TOWER SWITCHGEAR HOUSE.............................................. 237.10 WASTE GAS TREATMENT BUILDING................................................... 237.11 FIRE PUMP HOUSE........................................................................ 237.12 CONDENSATE DEMINERALIZER BUILDING (MUD HOUSE).......................... 237.13 CHLORINE BUILDING...................................................................... 247.14 SECURITY CAS BUILDING................................................................ 247.15 CIRCULATING WATER PUMP PIT ....................................................... 247.16 RECOMBINER BUILDING ................................................................. 247.17 TSC247.18 HIGH VOLTAGE SWITCHYARD .......................................................... 247.19 DISCHARGE STRUCTURE................................................................ 247.20 MAIN STACK................................................................................ 247.21 DEEPWELL PUMP HOUSE................................................................ 247.22 HYDROGEN/OXYGEN BULK STORAGE FACILITY..................................... 247.23 HYDROGEN/OXYGEN SUPPLY INTERMEDIATE VALVE STATION.................. 257.24 HYDROGEN/OXYGEN TURBINE BLDG ISOLATION VALVE STATION............... 257.25 HP/CHEMISTRY FILTER TRAIN (NORTH SIDE OF SECURITY CAS BLDG)......... 267.26 ISFSI / DRY STORAGE AREA (SOUTH OF PROTECTED AREA) ..................... 268.0 UNIT 1 REACTOR BUILDING.................................................................. 278.3.3 Torus Room, South Half............................................................... 278.3.4 RClC Room ............................................................................ 288.3.5 Div I RHR and Core Spray Corner Room ............................................ 288.4.3 Torus Room, North Half ............................................................... 298.4.4 CRD Room............................................................................. 308.4.5 Div II RHR and Core Spray Corner Room............................................ 318.4.6 HPCl Room............................................................................. 318.4.7 130 Ft Elevation, North Half........................................................... 328.4.8 158 Ft Elevation, North Half........................................................... 338.4.9 164 Ft HVAC and SBGT Room ....................................................... 348.4.10 Fuel Pool Cooling and Heat Exchanger Room....................................... 378.4.11 RWCU Equipment Room.............................................................. 378.4.12 203 Ft................................................................................... 388.5 REClRCULATION PUMP / ASD AREA MG SET ROOM ................................ 388.6 DRYWELL................................................................................... 399.0 TURBINE BUILDING ........................................................................... 409.2 TURBINE BUILDING OR WEST CABLEWAY............................................ 409.3 EAST CABLEWAY.......................................................................... 419.4 EAST CABLEWAY FOYER ................................................................ 4110.0 RADWASTE BUILDING ........................................................................ 4211.0 RECORDS....................................................................................... 4312.0COMMITMENTS ................................................................................ 43 V20Page 3 of 20SNC PANT .I.HATC I I Pg 85 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 1 OF 5*The Safe Shutdown Paths listed below indicate the Safe Shutdown Train that has been protectedfor a fire in the associated area. The Safe Shutdown path (1 OR 2) least impacted by the fire ineach area was identified AN..._D protected. It is assumed that only one path is available for shutdownfor the purpose of engineering analysis. This does NOT prevent operator use of systems outside ofthe protected path, IF they continue to function as required. For fire areas where protection of onepath cannot be achieved, such as the Main Control Room, Cable Spreading Room, AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND protected from the fire area.* Where circuit failures to protected path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are protected WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 3 (Path 1), Attachment 4 (Path 2), AN Attachment 5 (Path 3 OR RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, although NO_._I specifically protected OR analyzed, may survivethe fire. Circuit faults to unanalyzed equipment have NOT been evaluated.
+V20Page 4 of 20SNC LAN E.I. HTCHI IPg 86 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDUREI 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -UI 2 OF 5PREFIRE PLANDWG #CONTROL BUILDING112 FT. ELEV PASSAGEWAYS ORSERVICE AIR COMPRESSOR ROOMOIL RESERVOIR ROOMFREIGHT ELEVATOR OR STAIRWAYAC INVERTER ROOMSTATION BATTERY ROOM 1ASTATION BATTERY ROOM 1 BRPS BATTERY ROOM 1ARPS BATTERY ROOM lBWATER ANALYSIS ROOM ORHOT INSTRUMENT SHOPUNIT 1 130 FT ELEV PASSAGEWAYSHVAC ROOM -130 FT ELEVRPS MG ROOMVERTICAL CABLE CHASEANNUNCIATOR ROOMOIL CONDITIONER ROOMDC SWGR ROOM 1ADC SWGR ROOM lBHEALTH PHYSICS AREA ORRADWASTE LAB600V SWGR ROOM 1C600V SWGR ROOM 1DTRANSFORMERS ROOM lCDCO2 STORAGE TANK AREAMAIN CONTROL ROOMCABLE SPREADING ROOMCOMPUTER ROOMA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43 965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965SHT #5A, B10A,B6A, B13A,B11A,B12A,B15A, B1 4A, B8A, B24A,B25A, B26A,B26A,B27A,B33A, B30A, B32A,B23A, B28A,B29A,B31A,B46A, B48A,B44A,B45A, BPROTECTEDSAFE SHUTDOWNPATH21 and 221211 and 21 and 212212222122122REMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMS2CONTROL ROOM ROOFA4365A,A-43965 50A, B V20Page 5 of 20SNC LANTE. I HATH IPg 87 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE1 34AB-X43-001-1 13.1ATTACHMENT 2 Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 3 OF 5DIESEL GENERATOR BUILDINGDG BUILDING HALLWAYDG 1A BATTERY ROOMDG 1 B BATTERY ROOMDG lC BATTERY ROOMDG 1A DAY TANK ROOMDG 1 B DAY TANK ROOMDG 1 C DAY TANK ROOMDG 1A ENGINE ROOMDG lB ENGINE ROOMDG 1C ENGINE ROOMDG 1A SWGR ROOMDG 1B SWGR ROOMLDG lC SWGR ROOMPREFIRE PLANDWG #A-43966A-43966A-43966A-43 966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SHT #5A, B15A,B11A,B7A,B1 4A, B10A, B6A, B16A, B12A, B8A,B1 7A, B13A, B9A, B1 and 221 and 2121 and 21221221PROTECTEDSAFE SHUTDOWNPATHYARDCOOLING TOWERSINTAKE STRUCTUREPLANT SERVICE WATER VALVE PIT 2APLANT SERVICE WATER VALVE PIT 2BCONDENSATE STORAGE TANK AREANITROGEN STORAGE TANK AREATRANSFORMERSAUXILIARY BOILERCIRC WATER PUMP PITFIRE PROTECTION PUMP HOUSE,WEST AREAA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396674A, B thru 76C,D27A, B50A, B51A,B43A,B41 A, B56A, B61A,B52A,B46A,B1 and 21 and 221111 and 2NA21 and 2 V20Page 6 of 20SNC LANTE. I HATH IPg 88 of 118DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-00 1-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 4 OF 5REACTOR BUILDINGPREFIRE PLANDWG #PROTECTEDSAFE SHUTDOWNPATHSHT #51A,BDIV I RHR AND CORE SPRAY SECORNER ROOMDIV II RHR AND CORE SPRAY NECORNER ROOMCRD CORNER ROOMRCIC ROOMHPCI ROOMTORUS ROOM -SOUTH HALFTORUS ROOM -NORTH HALF130 FT ELEV -SOUTH130 FT ELEV -NORTHREClRC ASD ROOM 1ARECIRC ASD ROOM lBRWCU PUMP A ROOMRWCU PUMP B ROOM158 ELEV -WORKING FLOORDECANT PUMP ROOM164 FT ELEV HVAC ROOMFUEL POOL COOLING AREA SR-1205RRWCU EQUIPMENT AND SAMPLING ROOMSSUPPLY FAN ROOM185 FT WORKING FLOORTURBINE BUILDING EXHAUST FILTER ROOMSBGT ROOM203 FT WORKING FLOOR203 FT REFUELING AIR SUPPLY ROOM228 FT REFUELING FLOORDRYWELL AND TORUSA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965253A,B 154A, B 152A,B 255A,B 156A, B 257A,B 158A,B 259A,B 163A,B 264A,B 1 and 262A,B 162A,B 161A,B 161A,B 165A,B 167A,B 169A,B 169A,B 168A,B; 67A,B 171A,B 166A,B 173A,B 173A,B 174A,B 1 and 256A,B & 1 and 257A,B(Torus Room Only)PROTECTEDSAFE SHUTDOWNSHT # PATHPREFIRE PLANDWG #TURBINE BUILDINGEAST CABLEWAYTURBINE BUILDINGWEST CABLEWAYTURBINE DECKSTAIRWAYSEAST CABLEWAY FOYERA-43965A-43965A-43965A-43965A-43965A-4396534A,BN/A81A,B87A,B, 88A, BN/A34A, B122222 V20Page 7 of 20SNC LAN E.I. HTCHI IPg 90 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 3_ Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 1 1 OF 81.0 PATHWAY 1 TO SHUTDOWNSystems Required1.1.1 RHR, Pump A; RHR Service Water Pump A.1.1.2 RClC1.1.3 SRVs, Gand H1.1.4 Plant Service Water, Pump A1.1.5 RHR and RClC Emergency Room Ventilation System, A Coolers1.1.6 RPV Instrumentation1.1.7 Containment Instrumentation1.1.8 Drywell Air Supply1.1.9 Diesel Generator and Associated Electrical Equipment1.1.10 MSIVs1.1.11 Diesel Building Ventilation1.1.12 Intake Structure Ventilation V20Page 8 of 20SNC LAN E.I. HTCHI lPg 98 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001 -1 13.1ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 2 1 OF 82.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR System, Pump B; RHR Service Water Pump B.2.2.2 RHR and HPCI Room Coolers, B Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air2.2.7 Diesel Generator and Associated Electrical Equipment2.2.8 HPCI2.2.9 Core Spray (for Fire Area 1203 only)2.2.10 SRVs, A and C.2.2.11 MSIVs2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 9 of 20SNC LANTE. I HATH IPg 106 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 3 I OF 83.0 PATHWAY 3 TO SHUTDOWN3.1 Systems Required3.2.1. RHR System, Pump B; RHR Service Water Pump B3.2.2. RHR and RCIC Room Coolers3.2.3. Plant Service Water, Pumps A and B.3.2.4. RPV Instrumentation3.2.5. Containment Instrumentation3.2.6. Drywell Air3.2.7. Diesel Generator and Associated Electrical Equipment3.2.8. RCIC3.2.9. SRVs, C and G.3.2.10. MSIVs3.2.11. Diesel Building Ventilation3.2.12. Intake Structure Ventilation V20Page 10 of 20SOUTERNNUCEAR I DOUMET TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 114DOCUENTTITL: IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-00 1-2 15.0EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 3-18-15 DATE:N/A SS M/PM N/A DATE N/A 3-18-2015TABLE OF CONTENTSSection Page1.0 CONDITIONS..................................................................................... 32.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.1 Control Building Ventilation Fans............................................................ 75.2 Ventilation Restoration....................................................................... 75.3 Control Building Specific Area Actions...................................................... 85.4 Oil Storage Tank Room ...................................................................... 85.5 Station Battery Rooms (FA 2005) ........................................................... 85.6 RPS Battery Rooms.......................................................................... 85.7 130 ft elev. Passageways, HVAC Room and Lab .......................................... 85.8 Annunciator Room ........................................................................... 95.9 Oil Conditioner Room (FA 2023) ............................................................ 95.10 RPS MG Set Room and Vertical Cableway................................................. 95.11 DC Switchgear Rooms....................................................................... 95.12 Switchgear Access Hallway & 600V Switchgear Room 2C............................... 105.13 600V Switchgear Room 2D................................................................. 115.14 Transformer Room 2CD .................................................................... 125.15 Main Control Room, Cable Spreading Room or Computer Room ....................... 135.16 Control Building 112 ft Elevation Working Floor, Corridor, and Annunciator Logic Cabinet(FA 0001).................................................................................... 145.17 Water Analysis Room (FA 2006)........................................................... 146.0 DIESEL GENERATOR BUILDING............................................................. 156.1 Diesel generator Building Specific Area Index ............................................ 156.2 DG Battery Rooms.......................................................................... 156.3 DG Day Tank Rooms ....................................................................... 166.4 DG Engine Rooms.......................................................................... 186.5 DG 2A Swgr Room 2E (2R22-S005) ...................................................... 196.6 DG 1B Swgr Room 2F (2R22-S006) ...................................................... 206.7 DG 2C Swgr Room 2G (2R22-S007) ...................................................... 217.0 YARD ............................................................................................ 227.1 Plant Yard Specific Area Index............................................................. 227.2 Intake Structure ............................................................................. 227.3 Nitrogen Storage Tank AREA.............................................................. 23 V20Page 11 of 20PAGE2 OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.07.4 Main or Unit Auxiliary Transformer......................................................... 237.5 Startup Auxiliary Transformer .............................................................. 237.6 Auxiliary Boiler .............................................................................. 237.7 Waste Gas Treatment Building....................,......................................... 237.8 High Voltage Switchyard ................................................................... 237.9 Circulating Water Pump Pit ................................................................ 238.0 REACTOR BUILDING .......................................................................... 248.1 Reactor Building Ventilation................................................................ 248.2 Reactor Building Specific Area Index...................................................... 248.3 North Half of Reactor Building Below 185 ft ............................................... 258.4 ASD Rooms ................................................................................. 278.5 South Half of Reactor Building, and All of the 185 ft and 203 ft Elevations ............. 288.6 Drywell....................................................................................... 389.0 TURBINE BUILDING ........................................................................... 399.1 Turbine Building Specific Area Index ...................................................... 399.2 Turbine Building............................................................................. 399.3 Turbine Building Unit 2 East Cableway (2104)............................................ 409.4 Turbine Building East Cableway Foyer .................................................... 409.5 Turbine Building Unit 1 East Cableway.................................................... 4110.0 RADWASTE BUILDING ....................................................................... 4210.1 Ventilation Charcoal Filter trains ........................................................... 4211.0 RECORDS ..................................................................................... 4312.0 COMMITMENTS............................................................................... 43Attachments1 SAFE SHUTDOWN ACTIONS ................................................................. 442 PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 ................................ 853 SAFE SHUTDOWN PATHS FOR UNIT 2 FOR UNIT 1 FIRES .............................. 894 SAFE SHUTDOWN COMPONENT LIST PATH 1I............................................ 905 SAFE SHUTDOWN COMPONENT LIST PATH 2 ............................................ 966 SAFE SHUTDOWN COMPONENT LIST PATH 3 ........................................... 1037 LINKS NORMALLY OPEN TO SUPPORT APPENDIX R ................................... 1108 REFERENCE DRAWINGS LIST.............................................................. 1119 PLACARDS FOR 2H11-P601................................................................. 11310 KEY MILESTONES FORA FIRE OR FIRE DRILL .......................................... 114 V20Page 12 of 20SOUTERN UCLER IPAGEPLAN E. .HACHJ250OF 114DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.08.3 NORTH HALF OF REACTOR BUILDING BELOW 185 FT. ELEVATION8.3.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.3. LII8.3.2 This fire area consists of the following fire zones, perform the steps applicable to the area:STEP ZONE PAGE8.3.3 North Half of Torus Room ............................................................ 258.3.4 RCIC Corner Room ................................................................... 258.3.5 Div I RHR and Core Spray Corner Room............................................ 268.3.6 130 Ft Elevation, North Half.......................................................... 26Reactor Building Stairwell NO ACTIONS *158 Ft Elevation, North Half NO ACTIONS ** No additional actions are required beyond normal fire response actions.8.3.3 North Half of Torus Room8.3.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. Eli8.3.4 RClC Corner Room8.3.4.1 Stop RClC Pump Rm Coolers.* 2T41-B004A El* 2T41-B004B El8.3.4.2 Close RClC Steam Supply Isol AND Steam Supply Line Isol Valves.* 2E51-F007 El* 2E51-F008 El V20Page 13 of 20PAGE280OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-2 15.08.5 SOUTH HALF OF REACTOR BUILDING, AND ALL OF THE 185 FT AND 203 FTELEVATIONS8.5.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.5. LI8.5.2 This fire area consists of the following fire zones,perform the steps applicable to the fire zone: LISTEP ZONE PAGE8.5.3 South Half of Torus Room........... ............................................... 278.5.4 CRD Corner Room.................................................................. 288.5.5 Div II RHR and Core Spray Corner Room (Southeast) ........................... 298.5.6 HPCI Room.......................................................................... 298.5.7 130 Ft Elevation, South Half........................................................ 308.5.8 158 Ft. Elevation South Half........................................................ 308.5.9 164 Ft HVAC Room................................................................. 318.5.10 Fuel Pool Cooling And Heat Exchanger Room.................................... 328.5.11 Fuel Pool and RWCU Precoat Equipment Area................................... 328.5.12 185 Ft Elevation Working Floor .................................................... 338.5.13 185 Ft HVAC Room................................................................. 348.5.14 Standby Gas Treatment Room..................................................... 348.5.15 203 Ft Working Floor................................................................ 358.5.16 203 Ft HVAC Room................................................................. 358.5.3 South Half of Torus Room8.5.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. L[]
+V20Page 14 of 20SNC LAN E.I. HTCHI I Pg 85 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 1 OF 4*The Safe Shutdown Paths listed indicate the Safe Shutdown Train that has been analyzed for a firein the associated area. The Safe Shutdown Path (1 OR 2) least impacted by the fire in each areawas identified AND analyzed. It is assumed that only one path is available for shutdown for thepurpose of engineering analysis. This does NOT prevent Operator use of systems outside of theanalyzed path IFE they continue to function as required. For fire areas where protection of one pathCANNOT be achieved, such as the Main Control Room, Cable Spreading Room AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND~. analyzed.* Where circuit failures to analyzed path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are analyzed WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 4 (Path 1), Attachment 5 (Path 2) AND Attachment 6 (Path 3 -RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, may survive the fire. Circuit faults to unanalyzed equipmenthave NOT been evaluated.
+V20Page 15 of 20SNC LANTE. I HATH IPg 86 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 2 OF 4ANALYZEDPREFIRE PLAN SAFE SHUTDOWNCONTROL BUILDING DWG # SliT# PATH112 Ft Elev Passageways, Hot Instrument Shop A-43965 5A, B 2and Service Air Compressor RoomsOil Storage Tank Room A-43965 1 6A, B 1 and 2Freight Elevator or Stairway A-43965 6A, B 2Station Battery Room 2A A-43965 1 7A, B 2Station Battery Room 2B A-43965 1 8A, B 1AC Inverter Room A-43965 20A, B 1 and 2RPS Battery Room 2A A-43965 21A, B 1 and 2RPS Battery Room 2B A-43965 22A, B 1 and 2Water Analysis Room A-43965 1 9A, B 1Unit 2 130 Ft Elev Switchgear Hallway A-43965 24A, B 2Switchgear Hallway Enclosure A-43965 35A, B 2All Other 130 Ft Elev Passageways A-43965 24A, B 2HVAC Room -130 Ft Elev A-43965 25A, B 2RPS MG Room A-43965 26A, B 1Vertical Cable Chase A-43965 26A, B 2Annunciator Room A-43965 36A, B 2Oil Conditioner Room A-43965 42A, B 2DC SWGR Room 2A A-43965 39A, B 2DC SWGR Room 2B A-43965 41A, B 1Rad Protection Area and Radwaste Lab A-43965 23A, B 2600V SWGR Room 2C A-43965 37A, B 2I600OV SWGR Room 2D A-43965 38A, B 12CD Transformer Room A-43965 40A, B 1CO2 Storage Tank Area A-43965 46A, B 2LPCI Inverter Room A-43965 47A, B 2Main Control Room A-43965 48A, B 3Cable Spreading Room A-43965 44A, B 3Computer Room A-43965 45A, B 3Control Room Roof A-43965 50A, B 2Control Bldg East Corridor, Cold Lab, and A-43965 7A, B 2Adjacent Rooms, El 112 9A, BSwitchgear Access Hallway A-43965 35A, B 1 V20Page 16 of 20SNC LANTE. I HATH IPg 87 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 3 OF 4DIESEL GENERATOR BUILDINGDG Building HallwayDG 2A Battery RoomDG 1 B Battery RoomDG 2C Battery RoomDG 2A Day Tank RoomDG 1 B Day Tank RoomDG 2C Day Tank RoomDG 2A Engine RoomDG 1B Engine RoomDG 2C Engine RoomDG 2A SWGR Room 2EDG lB SWGR Room 2FDG 2C SWGR Room 2GPREFIRE PLANDWG #A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SliT#5A, B19A, B11A, B23A, B18A, B10A, B22A, B20A, B12A, B24A, B21A, B25A, B26A, BANALYZEDSAFE SHUTDOWNPATH1 and 221 and 2121 and 2121 and 21221YARDCooling TowersIntake StructurePlant Service Water Valve Pit 2APlant Service Water Valve Pit 2BCondensate Storage Tank AreaNitrogen Storage Tank Area500KV Reactor SwitchyardMain 500 KV SwitchyardAuxiliary BoilerCirc Water Pump PITRadwaste Dilution Valve PitDiesel 2A Fuel Oil Storage TankDiesel 20 Fuel Oil Storage TankA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396677A, B79A, B, C, D27A, B50A, B51A, B44A, B42A, B84A, B82A, B61A, B53A, B59A, B73A, B73A, B1 and 21 and 22121 and 21 and 22N/A2221 V20Page 17 of 20SNC LAN E.I. HTCHI IPg 88 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-00 1-2 J 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 J 4 OF 4PREFIRE PLANDWG #ANALYZEDSAFE SHUTDOWNPATHREACTOR BUILDINGSHT#Div I RHR and Core Spray NE Corner RoomDiv II RHR and Core Spray SE Corner RoomCRD Corner RoomRClC RoomHPCI RoomTorus Room -South HalfTorus Room -North Half130 Ft Elev -South130 Ft Elev -NorthRecirc ASD Room 2ARecirc ASD Room 2BRWCU Pump A RoomRWCU Pump B Room158 Elev South -Working Floor158 Elev North164 Ft Elev HVAC RoomFuel Pool Cooling Heat ExchangerFuel Pool and RWCU Precoat Equip Area185 Ft Supply Fan Room185 Ft Working Floor185 Ft HVAC RoomSBGT Room ASBGT Room B203 Ft Elevation203 Ft ElevationRefuel FloorDrywellA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-4396599A, B 2101AB 1102AB 1100A.,B 2103A.,B 1105A. B 1104AB 2107AB 1106A, B 2113A, B 1land 2114A, B 1land 2111A, B 1111A, B 1110A, B 1109A, B 2112A, B 1116A, B 1116A, B 1118A, B 1116A, B117A,B 1118AB 1115A, B 1115A, B 1122A, B 1120A,B 121A,B 1123A, B 1land 2104A,B 105A,B 1 and 2(Torus Area Only)108A, B 1Main Steam ChaseTURBINE BUILDINGTurbine Bldg Fire Area 2101164 Ft Elev Turbine Deckand other Fire Area 0101Turbine Building Below Turbine DeckWest CablewayStairwaysTurbine DeckEast CablewayA-43965A-4396549A, B 87-90A, BA-43965A-43965A-43965A-43965A-43965124-1 32A,133-1 36A,N/A128A, BN/A134A, B43A, BBB2122221 V20Page 18 of 20SNC LANTE. I HATH 1Pg 90 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001-2 15.0ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 1 1 OF 61.0 PATHWAY I TO SHUTDOWN1.1 Systems Required1.2.1 RHR, Pump A, RHR Service Water Pump A1.2.2 RCIC1.2.3 SRVs1.2.4 Plant Service Water, Pump A1.2.5 Emergency Room Coolers1.2.6 RPV Instrumentation1.2.7 Containment Instrumentation1.2.8 Drywell Air (Nitrogen System, Drywell Pneumatic System)1.2.9 Diesel Generator 2A and Associated Electrical Equipment1.2.10 MSIVs, Inboard1.2.11 Core Spray Loop A (for spurious ADS WHEN RHR Loop "A" NOT available)1.2.12 Diesel Building Ventilation1.2.13 Intake Structure Ventilation1.2 System Components1.2.1 RHR, Pump A and RHR Service Water, Pump ARequiredNormal PATH 1MPL No Mode SSD Mode2E11-C001A OFF ON2E11-C002A OFF ON2E11-F003A 0 02E 11-F004A 0 02E11-F006A C C2E11-F007A 0 VAR2E1l-F010 C C2E11-F011A C C2E11-F015A C 02E11-F016A C C2E11-F017A 0 02E11-F026A C C2E11-F028A C C2E11-F047A 0 02E11-F048A 0 VAR2E11-F065A 0 0RequiredNormal PATH 1MPL No Mod._._e SSD Mode2E11-F068A C VAR2E11-F073A C C2E1 1-F104A C C2E11-F119A C C2E11-K600A ON ON2E11-K603A ON ON2E11-N007A ON ON2E11-N015A ON ON2E11-N017A C 02E11-N017C C 02E11-N082A ON ON2E11-N104A ON ON2E11-N682A C VAR2E11-R600A ON ON2E11-R602A ON ON2E11-R603A ON ON V20Page 19 of 20SNC LANTE. I HATH IPg 96 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 2 I OF 72.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR, Pump B, RHR Service Water Pump B2.2.2 Emergency Room Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)2.2.7 HPCI2.2.8 Diesel Generator 2C and Associated Electrical Equipment2.2.9 Core Spray, Loop B (for spurious ADS WHEN RHR Loop "B" NOT[ available)2.2.10 SRVs2.2.11 MSIVs, Outboard2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 20 of 20SNC LANTE. I HATH IPg 103 of 114DOCMET ITE:DOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 6 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 3 1OF 73.0 PATHWAY 3 TO SHUTDOWN (REMOTE SHUTDOWN SYSTEMS)3.1 Systems Required3.2.1 RHR, Pump B, RHR Service Water Pump B3.2.2 Emergency Room Coolers3.2.3 Plant Service Water, Pump B3.2.4 RPV Instrumentation3.2.5 Containment Instrumentation3.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)3.2.7 RCIC3.2.8 Diesel Generators 2A and 2C and Associated Electrical Equipment3.2.9 SRVs3.2.10 MSIVs, Inboard3.2.11 Diesel Building Ventilation3.2.12 Intake Structure Ventilation V21Page 1 of 14. ITheMinmumSteam Cooling RPV Water Level for Hatch is: -180 inches. (Both5. The Minimum Steam Cooling RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. The temperature of the water injected into the RPV is 1 000F.6. Plant-specific data required to calculate the Minimum Steam Cooling RPV WaterLevel is as follows:a. Minimum active fuel length fraction which must be covered to maintain peakclad temperature below 1 5000F with injection.b. Active fuel lengthc. Water level at the bottom of the active fuelE. Minimum Zero-Injection RPV Water Level(LT 31) (LCT 31)1. The Minimum Zero-Injection RPV Water Level is defined to be the lowest RPVwater level at which the covered portion of the Reactor core will generate sufficientsteam to preclude any clad temperature in the uncovered portion of the core formexceeding 1 8000F. This Water Level is utilized to preclude significant fuel damageand hydrogen generation for as long as possible.2. This is the level at which Steam Cooling Without injection is used in the EOPs.A cold shutdown rod configuration must exist to use this core cooling method.3. The Minimum Zero-Injection RPV Water Level for Hatch is: -195 inches.(Both units)4. The Minimum Zero-Injection RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. No water is injected into the RPV.EOP-CURVES-LP-20306 Ver 3.0 GRAPH 2V22Page 1 of 2UNIT 1HEAT CAPACITY TEMPERATURE LIMIT0[-(i-TORUS WATER LEVEL (in)NOTE: May use SPDS Emergency Displays in place of this Graph.* Safe operating is below the applicable pressure line.
+V22Page 2 of 2SGRAPH 2Heat Capacity Temperature LimitEI-2602402202O00180160140120._'C')I..'IC')0Ra-x.I8098 120 140 160 180193200Torus Water Level (in)Note: May use SPDS in place of this GraphREQUIRED if above curve for existing RPV pressEOP-CURVES-20306FIG 2Page 61 of 75 V23Page 1 of 4Mare Condenser Offgas3.7.63.7 PLANT SYSTEMS3.7.6 Main Condenser OffgasLCO 3.7.6tiT e gross gamma actvity rate of the noble gases measured at the maincondenser evacuation system pretreatmentl monitor station shall be240 mCi/seond. ,MODE 1,MODES 2 and 3 with any main steam line not isolated and steam jet airejector (SJAE) in operation.APPLICABILITY:ACTIONS___________ _____ ___CONDITION REOUIRED ACTION COMPL=ETION TIMEA. Gross gamma activity rate A.1 Restore gross gamma 72 hoursof the noble gases not activity rate of the noblewithin limit, gases to limit.B8 Required Action and B. 1 Isolate all main steam 12 hoursassociated Completion linesTime not met.OR8.2 Isolate SJAE 12 hoursORRB.3.1 Be in MODE 3 12 hoursANDB,3.2 Be in MODE 4. 36 hootsHATCH UNIT 23.7-16HATC UNI 2 37-16Amendment No. 135 CDCD0(0CDN, 0-9CD V23, Page 4 of 4SU3 Reactor coolant activity greater than Technical Specification allowable limits.Operating Mode:Power OperationStartupHot StandbyHot Shutdown(1 OR 2)Emergency Action Levels:1. Pretreatment Radiation Monitor reading greater than 240,000 pCi/sec for greater than60 minutes.According to Tech. Spec. Bases 3. 7.6 page B3. 7-31 and Tech. Spec. section 3. 7.6page 3. 7-16, the gross gamma activity rate of the noble gases measured at the maincondenser evacuation system pretreatment monitor station shall be <.240mCi/secondor <240, O00pCifsecond. According to 64C1-0CB-006-1/2 procedures the offgaspretreatment radiation monitors are 1/2D1 1-K601 and 1/2D1 1-K602OR2. Sample analysis indicates that the reactor coolant specific activity is EITHER:* Greater than 0.2 pCi/gm and less than or equal to 2.0 pCi/gm doseequivalent 1131 for greater than 48 hours.* Greater than 2.0 pCi/gm dose equivalent 1131.According to Tech. Spec. Bases 3. 4.6 page B3.4-25 and Tech. Spec. section 3. 4.6page 3.4-11, the specific activity of the reactor coolant shall be limited to DOSEEQUIVALENT 1-131 specific activity 0.2 IJCi/gm. A condition >0.2 pCi/gm but <2.OIJCi/gm must be restored within 48 hours. A condition > 2pCi/gm requires immediateaction, V24Page 1 of 1RCS Specifi Activity3.4.63.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 RCS Specific ActivityLCO 3.4.6Thre specifi activty of the reactor coolant shag be limited to DOSEEQUIVALEFNT 1-131 speific activit 0.2 pC~igm.APUCBIUTrY:MODE 1,MODS 2 and 3 with any m'aui steam line not isolated.ACTIONSCO,,NDmON REQUIRED ACTION COMPLETION TIMEA.Reacto colaspecifi NOTESacbvtty 0.2 &aCim and LCO 3.0.4.c is apl:iicable.1 2.0 DOSElEQUIVALENT 1-131.A.1 Determine DOSE Once per 4 hoursEQUIVALENT 1-131.ANDA.2 Restore DOSEEQUIALENT 1-131 toB. Required Ac~tion an B.1 Determine DOSE Once per 4 hoursassociated Completion EQUIVALENT 1-131.Time of Cocst A notQR B2.1 Isolate all main steam 12 hoursReactor coolant spciiactivity >2.0 DOSE OEQUIVALENT 1-131.B22.1 BeminMODE 3. 12 IurS8222 Be in MODE 4. 36 hoursHATCH UNIT 23.4-11HATH UIT 34-1 AmndmntNo. 210 V25Page 1 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (Refs. 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation and thecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 1 .-3RVSOB 3.4-13REVISION 0 V25Page 2 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment canI(continued)HATCH UNIT 1 B341 EIIN5B 3.4-14REVISION 59 V25Page 3 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._IWith RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 1 .-5RVSOB 3.4-15REVISION 0 V25Page 4 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (References 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation andthecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 2 B341 EIIN7B 3.4-14REVISION 77 I V25Page 5 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment can(continued)HATCH UNIT 2 B341 EIIN7B 3.4-15REVISION 77 I V25Page 6 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in' anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._1!With RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 28341REION7B 3.4-16REVISION 77 V1 8Page 1 of 10SOUTHERN NUCLEARIPLANT El. HATCHPAGE 9 OF 30DOUMNTTILE t DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL t 34AB-T22-003-1 5.14ATTACHMENT 2 ATT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1G31-R604) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1H11-P614, 1G31-R604 Value Value0F o158' ELEVATION AREA (RWCU)101 B Pump Room (1G31-N016D) 150 212.5102 B Pump Room DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Room (1G31-N016B) 150 212.5104 Hx Room DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B (1E11-N009B) 150 212.5108 RHR/CS B DIFF(1E11-N030B/1E11-N029B) 40 98HPCl ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245110 HPCI VENT AIR DIFF (1E41-N029B/1E41-N028B) NA NA(not used)RCIC ROOM AREA111 Emer Area CIr (1 E5I-N023B) 167.5 310112 RCIC VENT AIR DIFF (1E51-N022B/1E51-N021 B) NA NA(not used)TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1E51-N025D) 167.5 212.5115 VENT AIR DIFF (1E51-N027B/1E51-N026B) 42 102116 VENT AIR DIFF (1 E51-N027D/1 E51-N026D) 42 102HPCI PIPE PENETRATION ROOM117 1E41-N046B 150 212.5Posted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 2 of 10PAGE 10 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 3 ATTACH. PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1 G31 -R608) 1 OF 1Max Normal Max SafeSECONDARY CONTAINMENT TEMP Operating Operatingon 1IH11-P614, 1G31-R608 Value ValueoF o158' ELEVATION AREA (RWGU)101 A Pump Room (1G31-N016C) 150 212.5102 A Pump Room DIFF (1G31-N022B/1G31-N023B) 67 98103 Hx Room (1G31-N016E) 150 212.5104 Hx Room DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF (1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A (lE1 1-N009A) 150 212.5108 RHRICS A DIFF (1EI11-N030A/1 E11-N029A) 40 98HPCI ROOM AREA109 Pump Room (1E41-N024) 167.5 245110 Emer Area CIr (1 E41 -N030A) 167.5 245111 HPCl VENT AIR DIFF (1 E41-N029A/11E41-N028A) NA NA(not used)_________RClC ROOM AREA112 Pump Room (1E51-N011) 167.5 310113 Emer Area CIr (1E51-N023A) 167.5 310114 RCIC VENT AIR DIFF (1 E51-N022A/1 E51-N021A) NA NA(not used)TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-N025C) 167.5 212.5117 VENT AIR DIFF (1 E51-NO26AI1 E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1 E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm TnI 1B21-N014 192.5 300120 1B21-N016AN0O16B DIFF 60 150HPCI PIPE PENETRATION ROOM 150 212.5121 1E41-N046APosted 1 H11-P614MGR-0009 Rev 5.0 V1 8Page 3 of 10PAGE 27 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE ]DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2Max MaxSECONDARY CONTAINMENT TEMPNoml Sfon IHI1-P614, 1G31-R604 0158' ELEVATION AREA (RWCU)101 B Pump Rm (1G31-N016D) 150 212.5102 B Pump Rm DIFF (1G31-N022C/1G31-N023C) 67 98103 Hx Rm (1G31-N016B) 150 212.5104 Hx Rm DIFF (1G31-N022D/1G31-N023D) 67 98105 Ph Sep Rm (1G31-N016F) 150 212.5106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98NORTHEAST DIAGONAL AREA107 RHR/CS B(1E11-N009B) 150 212.5108 RHR/CS B DIFF (1E11-N030B/1E11-N029B) 40 98HPCI ROOM AREA109 Emer Area CIr (1E41-N030B) 167.5 245RCIC ROOM AREA111 Emer Area Clr (1 E51-N023B) 167.5 310TORUS ROOM AREA113 Southwest Wall (1E51-N025B) 167.5 212.5114 Northeast Wall (1 E51-N025D) 167.5 212.5115 Vent Air DIFF (1E51-N027B/1E51-N026B) 42 102116 Vent Air DIFF (1E51-N027D/1E51-N026D) 42 102HPCl PIPE PENETRATION ROOM117 1E41-N046B 150 212.5RDG RDG1 23Reference 34AB-T22-003- 1MGR-0009 Rev 5.0 Vi18Page 4 of 10PAGE 28 OF 30SOUTHERN NUCLEARIPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14ATTACHMENT -9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP Max Maxon 1H11-P614, 1G31-R608 Normal Safe158' ELEVATION AREA (RWCU)101 A Pump Rm (1G31-N016C) 150 212102 A Pump Rm DIFF (1G31-N022BI1E51-N023B) 67 98103 Hx Rm (1G31-N016E) 150 212.5104 Hx Rm DIFF (1G31-N022A/1G31-N023A) 67 98105 Phase Sep Rm (1G31-N016A) 150 212.5106 Phase Sep Rm DIFF(1G31-N022E/1G31-N023E) 67 98SOUTHEAST DIAGONAL AREA107 RHR/CS A(1E11-N009A) 150 212.5108 RHR/CS A DIFF (1E11-N030A/1E11-N029A) 40 98HPCl ROOM AREA109 Pump Rm (1E41-N024) 167.5 245110 EmerArea Clr(1E41-N030A) 167.5 245RCIC ROOM AREA112 Pump Rm (1E51-N011) 167.5 310113 EmerArea CIr (1E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (1E51-N025A) 167.5 212.5116 Southeast Wall (1E51-NO25C) 167.5 212.5117 VENT AIR DIFF (1E51-N026A11E51-N027A) 42 102118 VENT AIR DIFF (1E51-N026C/1E51-N027C) 42 102MAIN STEAM LINE TUNNEL AREA119 Main Stm Tnl (1B21-N014) 192.5 300120 1B21-N016A/N016B DIFF 60 150HPCI PIPE PENETRATION ROOM121 1E41-N046A 150 212.5I/RDG RDG RDG1 2 3I________Iec 4B-2-0-MGR-0009 Rev 5.0 V18Page 5 of 10PAGE 29 OF 30SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL 34AB-T22-003-1 5.14ATTACHMENT 10 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT PARAMETERS 1 OF 1Imax 14" aow8rTelw.Ir Irt' 3TabowSTe~ev.t#' aovSe lteev.DIAGONALAREA150212.5I.IV ROOMAIEA wI' h svIo"fl vi" IT 71e,CO4hNMENREFA RADIATIONIMONITORS I [g~11.SS 1211UV~jteVaeIEREL FLO(F AREA1Reathe.J iee (1D21-KG00A) 50 10002 a u(IO141-01 B) 50 10(003 P.uuI o(1O21-K60lD) 50 10004 Dr~weIl 50 10005 SpeltFtmlPool&New~uelStcrage(1D21.K501M 50 10005RB20Wor~ru(1D21K0 X) 50 7 SpentFuel PoC DeuinvEquip{1O21.01C) 150 I1Q000eFu.PocDsrmin, Pmn(1D21.K17) 50 10 ___9 R81irWokArea(1D214K601K) 50 1 00010 RxbSarjiRzdkue (ID214K601L) 50 1 000)11 50 IOQ0012 NothCRVHCU(1021-IQD1P) 50 I100014 R8130N.E~odinku(1D21.K601G) 50 I100015 50 ]1000 __ELEVATION SOUTH AREA16 50 100017 SoutthCAOHCJ(1D2FH(0tN) 50 1000 _18 RCCEEupSWDmgna(1O21.KO1V) 50 I1000NORfN"TI~LAOA AREA19 CR)PumpiWOIagvnI(1D21.(801W) 50 I1000NOfES G4LAREA20 CS&RJIRN~.Edg(1D21-KIE01Y) 50 1000SOUT~fJST ENA-(NAL ARE --_ -21 CS&Rk-IlS,,EDigoza{IDT2.K6O1R) 50 1 (000!J7 ELEVATION AREA ET22 HFOTuwtmieAlui1D214t01T) 150 I10(001OP114S-~1933~I l=l 1I34AB-T22-O03-1OPS-1 933MGR-0009 Rev 5.0 V1 8Page 6 of 10PAGE 9 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOUMNTTILE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 2 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 1(2G31-R604)_________MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H11-P614, OPERATING OPERATING2G31-R604 VALUE VALUE&deg;F &deg;F158' ELEVATION AREA (RWCU)101. B pump room (2G31-N016B) 150 215102. B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103. Hx Room (2G31-N016D) 150 215104. Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105. Valve Nest (2G31-N016F) 150 215106. Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 99SOUTHEAST DIAGONAL AREA107. RHR/CS B (2E11-N009B) 150 190108. RHR/CS B DIFF (2E11-N030B/2E11-N029B) 40 74HPCI ROOM AREA109. Emer area clr (2E41-N030B) 167.5 245110. HPCl vent air DIFF (2E41-N029B/2E41-N028B) NA NA(not used)______ ____RClC ROOM AREA111. Emer Area CIr (2E51-N023B) 167.5 310112. RCIC vent air DIFF (2E51-N022B/2E51-N021B) NA NA(not used)______ ____TORUS ROOM AREA113. Northwest Wall (2E51-N025B) 167.5 212.5114. Southeast Wall (2E51-N025D) 167.5 212.5115. Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116. Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117. 2E41-N046B 167.5 212.5 Vi18Page 7 of 10PAGE 10 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-2 4.2ATTACHMENT 3 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (2G31 -R608) 1 OF 1MAX NORMAL MAX SAFESECONDARY CONTAINMENT TEMP ON 2H1 1-P614, OPERATING OPERATING2G31-R608 VALUE VALUE&deg;F &deg;F158' ELEVATION AREA (RWCU)101. A Pump Room (2G31-N016A) 150 215102. A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 99103. Hx Room (2G31-N016C) 150 215104. Hx Room DIFF (2G31-N023C/2G31-N022C) 67 99105. Phase Sep Rm (2G31-N016E) 150 215106. Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 99NORTHEAST DIAGONAL AREA107. RHR/CS A (2E1 1-N009A) 150 215108. RHR/CS A DIFF (2E11-N030AN2E11-N029A) 40 74HPCI ROOM AREA109. Pump Rm (2E41-N024) 167.5 245110. Emer Area CIr (2E41-N03OA) 167.5 245111. HPCI Vent Air DIFF (2E41-N029A/2E41-N028A) NA NA(not used)__________RCIC ROOM AREA112. Pump Rm (2E51-N011) 167.5 310113. Emer Area CIr (2E51-N023A) 167.5 310114. RCIC Vent Air DIFF (2E51-N022A12E51-N021A) NA NA(not used)TORUS ROOM AREA115. West Wall (2E51-N025A) 167.5 212.5116. Northeast Wall (2E51-N025C) 167.5 212.5117. Torus Vent Air DIFF (2E51-N027A/2E51-N026A) 42 98118. Torus Vent Air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119. Main Steam Tunnel (2B21-N014) 192.5 310120. Main Stm Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150HPCI PIPE PENETRATION ROOM121. 2E41 -N046A 167.5 212.5 V18Page 8 of 10PAGE 30 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT _9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2SECONDARY CONTAINMENT TEMPMMAon 2H11-P614, 2G31-R604 NORMALj SAFE158' ELEVATION AREA (RWCU)101 B pump room (2G31-N016B) 150 215102 B pump room DIFF (2G31-N023B/2G31-N022B) 67 99103 Hx Room (2G31-NO16D) 150 215104 Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99185' ELEVATION AREA (RWCU)105 Valve Nest (2G31-N016F) 150 215106 Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 9SOUTHEAST DIAGONAL AREA107 RHR/CS B (2E11-N009B) 150 J190108 RHR/CS B DIFF (2E1 1-N030B/2G31-N029B) 40 J 74HPCI ROOM AREA109 Emer Area CIr (2E41-N030B) I67.5 245RCIC ROOM AREA111 Emer Area CIr (2E51-N023B) 16. 1TORUS ROOM AREA113 Northwest Wall (2E51-N025B) 167.5 212.5114 Southeast Wall (2E51-N025D) 167.5 212.5115 Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98116 Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98HPCI PIPE PENETRATION ROOM117 2E41-N046B Ii7.5I 212.5Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 SOUTHERN NUCLEARPLANT E.I. HATCHVi18Page 9 of 10PAGE 31 OF 37DOCMET ITE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAINMENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 9 ATTACHMENT PAGE:TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2SECONDARY CONTAINMENT TEMP MAX MAXon 2H11-P614, 2G31-R608 NORMAL[ SAFE158' ELEVATION AREA (RWCU)101 A Pump Room (2G31-N016A) 150 21102 A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 9103 Hx Room (2G31-N016C) 150 21104 Hx Room DIFF (2G31-N023C/2G31-N022C) 67 9105 Phase Sep Rm (2G31-N016E) 150 21106 Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 9NORTHEAST DIAGONAL AREA107 RHR/CS A (2E1 1-N009A) 150 21108 RHR/CS A DIFF (2E11-N030AI2E11-N029A) 40 174HPCl ROOM AREA109 Pump Rm (2E41-N024) 167.5 245110 Emer Area Clr(2E41-N030A) 167.5/ 245RClC ROOM AREA112_Pump Rm_(2E51-N011) 167.5 _310113 Emer Area Clr (2E51-N023A) 167.5 310TORUS ROOM AREA115 West Wall (2E51-N025A) 167.5 212.5116 Northeast Wall (2E51-N025C) 167.5 212.5117 Torus vent air DIFF (2E51-N027A12E51-N026A) 42 98118 Torus vent air DIFF (2E51-N027C/2E51-N026C) 42 98MAIN STEAM LINE TUNNEL AREA119 Main Steam Tunnel (2B21-N014) 192.5 310120 Main Steam Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150RDG RDG1 RDG1 2 3-B_HPCl PIPE PENETRATION ROOMI121 2E41,N046A [167.5 212.5_Values displayed in the NORM column (green) represent the valuesat 100% rated thermal power, summertime conditions.POSTED AT 2H1 1-P614 V1 8Page 1 0 of 10PAGE 35 OF 37SOUTHERN NUCLEARPLANT E.I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2ATTACHMENT 1"1 ATTACHMENT PAGE:TITLE: SECONDARY CONTAI NMENT PARAMETERS 1 OF 1Table 4 o'9tA~hG~iWAfliI I C0NbleN 5 A101102AREA WATER LEVELSMax NanulMaxSafe.___ 4" r/5T'sia 33 isv .1.AREA4"iow ST ealeion!$"o8T 1ev'.4icvelTelwian 27.bovel7'elw.diov.STal.vglwit#' above $'t' 4" isve 8'uleiion14" isy rr sh,4 aov 57' ekydontt" above 37' .ev.Table 6 ARIA MOR10.3yaw awS UUHd113 l 51-N058) I167.5 212.5114 Sou WlbeI (2E514NU50) l167.5 212.5116 ToqusM VtOIFF 42 901 A Pw~own%2;G31.#408Ao mpRoooN2G314 t3Phu Sep Rm(2m1.N01E)Va15067'so57150RiVa21599215982151 Reac had (2D21-K601A) 50 1Q0003 SfouIlo&NswFu l~g.(2f21.KBO1M) 50 10004 ahFboor(2D214(SI11K) 5o 10o0G Reeor Vesse!RFloor (2Q21.K811 L) 50 1Q00063 (2D214,SO1T) 50 10]007 HV o&#xa2;W 50 1008 Spn u olPsaea 50 10009 RB 18 qelegIoor(2O21..KO0R) 50 100010 R81W Samispuue t.lme(221.(8O1S) 50 1Q000I'I R818 cou~rol pa-.(2O21-K601U) 15O t000__13 S reaIW (2D21.(501D) 50 1000__15Dean um eupmntronara 50 1000__`10001307 ELEVATION ARE.A (NSRUThWSN(R11PMB(2T2IMOIF) L AO RtOA217 50 .100022 RC1S.W4~odgAii(2D21,,K601X) 50 .100023 cs&rRls~dagoi(2V214WO1Y) 150 1000O115 16+7.5 21 21542 198l34AB-.T22-003-2OPS-1932OPS-1 932 V19Page 1 of 4PAGE 2 OF 3SOUTHERN NUCLEARPLANT E.I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:ARP'S FOR CONTROL PANEL 2H1 1-P657, 34AR-657-901-2 I 23.1ALARM PANEL 1UNIT 22H11-P657 -1 (LEFT)657-001 657-002 657-00.3 557-004 57-005 657-006 657-007 657-008 657-009657-019 657-020 657-021 57-02 657-023 657-024 657-025 657-026 657-027657-037 657 -03 6 57-03;; 57-040 6 7-041 657-042 657-043 657-044 657-045657-055 657-05S G57 057 657-058 -5705 657-060 657-061 657-062 657-063657-07 657-074 657-075 657-0Th 657-77 657-07 657-079 657-080 657-081657-091 57 0 2 657-093 557-094 657-095 657 096 65-097 657-098 657-0992H11-P657 -1 (RIGHT)657-010 657-011 G57-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 ss57-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 65 7-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-0B3 65-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108Level Of Use ARPsCONTINUOUS ALLREFERENCE NoneINFO None Vi19Page 2 of 41.0 IDENTIFICATION:ALARM PANEL 657__ _______SEISMIC* INSTRUMENTATIONTRIGGEREDDEVICE: SETPOINT:2L51-N022 0.08 g horizontal, 0.54 g vertical2L51 -N024 0.18 g horizontal, 0.063 vertical2.0 CONDITION: 3.0 CLASSIFICATION:[ EQUIPMENT STATUSMotion has been detected in Unit 2 Reactor Building on4.LOAINelevation 87' or 185' 4 H0 LOCATION5.0 OPERATOR ACTIONS:5.1 At Panel 1 Hi11-P701, check for further indications of a seismic eventby monitoring Peak Shock Annunciator, 1 L51-R620,for 12.7 Hz amber lights (> 0.08g, OBEY) and 12.7 Hz red lights (> 0.15g, DBE). LII5.2 Refer to Seismic Instrumentation Earthquake Response Manual, SX-18271,for guidance in analyzing seismic data. LI5.3 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. LI5.4 Enter NMP-EP-1 10, Emergency Classification Determination and Initial Action. LI5.5 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. LI6.0 CAUSES:Seismic event
+==7.0 REFERENCES==
+: 8.0 TECH. SPECS./TRMIODCMIFHA:7.1 H-16319, Seismic Measurement Equip Control TRM T3.3.6 Seismic MonitoringPanel & Instrumentation. Instrumentation7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-048-2VER 4.1MGR-0048 Ver. 5.0 Vi19Page 3 of 4UNIT 1IH11-P657 -1 (RIGHT)657-010 657-011 657-012 657-013 657-014 657-015 657-016 657-017 657-018657-028 657-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054657-064 657-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072657-082 657-083 657-084 657-085 657-086 657-087 657-088 657-089 657-090657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108RECORDSThere are no records generated by the procedureCOMMITMENTSNONEMGR-0001 Ver. 4 V19Page 4 of 41.0 IDENTIFICATION:ALARM PANEL 657________SEISMIC PEAKSHCKRECORDERJDEVICE: SETPOINT:1 L51-Vbc-R620 Not available5.0 OPERATOR ACTIONS:5.1 At Panel 1~ H1-P701, check for further indications of a seismic event,by monitoring 1L51-Vbc-R620, Peak Shock Annunciators,for 12.7 Hz amber lights (> 0.08g, OBE) AND 12.7 Hz red lights (_? 0.15g, DBE). El5.2 IF no other indications of a seismic event are present, check the following:* Peak Shock Annunciator, 1L51-vbc-R602, plugged in on Panel 1H1 1-P701 El* BRKR 3 on 120/208V Essential AC Cab, 1R25-S065 El5.3 Refer to SX-18271, Seismic Instrumentation Earthquake Response Manual,for guidance in analyzing seismic data. El5.4 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon. El5.5 Enter 73EI-EIP-001-0, Emergency Classifications and Initial Actions. El5.6 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. El6.0 CAUSES:6.1 Seismic event6.2 Power failure
+==7.0 REFERENCES==
+: 8.0 TECH. SPEC.ILCO:7.1 H-16319, Seismic Measurement Equipment Control Unit 2, TRM T3.3.6 Seismic MonitorsPanel and Instrumentation.7.2 H-17978, Seismic Measurement Equip Sys L51Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-066-1IVer. 3.0MGR-0048 Ver. 5AG-MGR-75-1101 V20Page 1 of 20SOUTERN UCLAR DCUMNT TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 118DOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-1 13.1EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 8-1 1-14 DATE:N/A SSM /PM N/A DATE N/A 9-11-141.0 CONDITIONSA fire exists at Plant E. I. Hatch. This procedure provides information AND actions necessary tomitigate the consequences of fires AND to maintain an operable shutdown train following firedamage to specific areas.TABLE OF CONTENTSSection Paae2.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.4 112 FT. ELEVATION ......................................................................... 75.5 OIL STORAGE TANK ROOM ............................................................... 75.6 STATION BATTERY ROOMS ............................................................... 85.7 RPS BATTERY ROOMS..................................................................... 85.8 130 FT ELEV. PASSAGEWAYS, HVAC ROOM, HP AREA, RADWASTE LAB ......... 85.9 RPS MG SET ROOM ........................................................................ 85.10 OIL CONDITIONER ROOM ................................................................. 95.11 DC SWITCHGEAR ROOMS................................................................. 95.12 600V SWITCHGEAR ROOM iC ............................................................ 95.13 600V SWITCHGEAR ROOM 1D........................................................... 105.14 TRANSFORMER lCD ROOM ............................................................. 105.15 MAIN CONTROL ROOM, CABLE SPREADING ROOM OR COMPUTER ROOM ....115.16 CONTROL ROOM ROOF .................................................................. 135.4 112 FT. ELEVATION........................................................................ 146.0 DIESEL GENERATOR BUILDING ............................................................. 156.2 DG BATTERY ROOMS..................................................................... 156.3 DG DAY TANK ROOMS.................................................................... 166.4 DG ENGINE ROOMS ...................................................................... 176.5 DG 1A SWGR ROOM 1E (1R22-S005).................................................... 186.6 DG lB SWGR ROOM iF (1R22-S006).................................................... 196.7 DG 1C SWGR ROOM 1G (1R22-S007)................................................... 207.0 YARD ............................................................................................. 217.2 COOLING TOWER ......................................................................... 227.3 INTAKE STRUCTURE...................................................................... 227.4 CONDENSATE STORAGE TANK AREA ................................................. 227.5 NITROGEN STORAGE TANK AREA...................................................... 23 SOUTHERN NUCLEARPLANT E. I. HATCHIV20Page 2 of 20PAGE2 OF 118DOCMEN TTLE IDOCUMENT NUMBER: IVERS ION NO:FI RE PROCEDURE 34AB-X43-001-.1 j 13.17.6 MAIN OR UNIT AUXILIARY TRANSFORMER............................................ 237.7 STARTUP AUXILIARY TRANSFORMER................................................. 237.8 AUXILIARY BOILER........................................................................ 237.9 COOLING TOWER SWITCHGEAR HOUSE.............................................. 237.10 WASTE GAS TREATMENT BUILDING................................................... 237.11 FIRE PUMP HOUSE........................................................................ 237.12 CONDENSATE DEMINERALIZER BUILDING (MUD HOUSE).......................... 237.13 CHLORINE BUILDING...................................................................... 247.14 SECURITY CAS BUILDING................................................................ 247.15 CIRCULATING WATER PUMP PIT ....................................................... 247.16 RECOMBINER BUILDING ................................................................. 247.17 TSC247.18 HIGH VOLTAGE SWITCHYARD .......................................................... 247.19 DISCHARGE STRUCTURE................................................................ 247.20 MAIN STACK................................................................................ 247.21 DEEPWELL PUMP HOUSE................................................................ 247.22 HYDROGEN/OXYGEN BULK STORAGE FACILITY..................................... 247.23 HYDROGEN/OXYGEN SUPPLY INTERMEDIATE VALVE STATION.................. 257.24 HYDROGEN/OXYGEN TURBINE BLDG ISOLATION VALVE STATION............... 257.25 HP/CHEMISTRY FILTER TRAIN (NORTH SIDE OF SECURITY CAS BLDG)......... 267.26 ISFSI / DRY STORAGE AREA (SOUTH OF PROTECTED AREA) ..................... 268.0 UNIT 1 REACTOR BUILDING.................................................................. 278.3.3 Torus Room, South Half............................................................... 278.3.4 RClC Room ............................................................................ 288.3.5 Div I RHR and Core Spray Corner Room ............................................ 288.4.3 Torus Room, North Half ............................................................... 298.4.4 CRD Room............................................................................. 308.4.5 Div II RHR and Core Spray Corner Room............................................ 318.4.6 HPCl Room............................................................................. 318.4.7 130 Ft Elevation, North Half........................................................... 328.4.8 158 Ft Elevation, North Half........................................................... 338.4.9 164 Ft HVAC and SBGT Room ....................................................... 348.4.10 Fuel Pool Cooling and Heat Exchanger Room....................................... 378.4.11 RWCU Equipment Room.............................................................. 378.4.12 203 Ft................................................................................... 388.5 REClRCULATION PUMP / ASD AREA MG SET ROOM ................................ 388.6 DRYWELL................................................................................... 399.0 TURBINE BUILDING ........................................................................... 409.2 TURBINE BUILDING OR WEST CABLEWAY............................................ 409.3 EAST CABLEWAY.......................................................................... 419.4 EAST CABLEWAY FOYER ................................................................ 4110.0 RADWASTE BUILDING ........................................................................ 4211.0 RECORDS....................................................................................... 4312.0COMMITMENTS ................................................................................ 43 V20Page 3 of 20SNC PANT .I.HATC I I Pg 85 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 1 OF 5*The Safe Shutdown Paths listed below indicate the Safe Shutdown Train that has been protectedfor a fire in the associated area. The Safe Shutdown path (1 OR 2) least impacted by the fire ineach area was identified AN..._D protected. It is assumed that only one path is available for shutdownfor the purpose of engineering analysis. This does NOT prevent operator use of systems outside ofthe protected path, IF they continue to function as required. For fire areas where protection of onepath cannot be achieved, such as the Main Control Room, Cable Spreading Room, AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND protected from the fire area.* Where circuit failures to protected path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are protected WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 3 (Path 1), Attachment 4 (Path 2), AN Attachment 5 (Path 3 OR RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, although NO_._I specifically protected OR analyzed, may survivethe fire. Circuit faults to unanalyzed equipment have NOT been evaluated.
+V20Page 4 of 20SNC LAN E.I. HTCHI IPg 86 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDUREI 34AB-X43-001-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -UI 2 OF 5PREFIRE PLANDWG #CONTROL BUILDING112 FT. ELEV PASSAGEWAYS ORSERVICE AIR COMPRESSOR ROOMOIL RESERVOIR ROOMFREIGHT ELEVATOR OR STAIRWAYAC INVERTER ROOMSTATION BATTERY ROOM 1ASTATION BATTERY ROOM 1 BRPS BATTERY ROOM 1ARPS BATTERY ROOM lBWATER ANALYSIS ROOM ORHOT INSTRUMENT SHOPUNIT 1 130 FT ELEV PASSAGEWAYSHVAC ROOM -130 FT ELEVRPS MG ROOMVERTICAL CABLE CHASEANNUNCIATOR ROOMOIL CONDITIONER ROOMDC SWGR ROOM 1ADC SWGR ROOM lBHEALTH PHYSICS AREA ORRADWASTE LAB600V SWGR ROOM 1C600V SWGR ROOM 1DTRANSFORMERS ROOM lCDCO2 STORAGE TANK AREAMAIN CONTROL ROOMCABLE SPREADING ROOMCOMPUTER ROOMA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43 965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965SHT #5A, B10A,B6A, B13A,B11A,B12A,B15A, B1 4A, B8A, B24A,B25A, B26A,B26A,B27A,B33A, B30A, B32A,B23A, B28A,B29A,B31A,B46A, B48A,B44A,B45A, BPROTECTEDSAFE SHUTDOWNPATH21 and 221211 and 21 and 212212222122122REMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMSREMOTE SHUTDOWNSYSTEMS2CONTROL ROOM ROOFA4365A,A-43965 50A, B V20Page 5 of 20SNC LANTE. I HATH IPg 87 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE1 34AB-X43-001-1 13.1ATTACHMENT 2 Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 3 OF 5DIESEL GENERATOR BUILDINGDG BUILDING HALLWAYDG 1A BATTERY ROOMDG 1 B BATTERY ROOMDG lC BATTERY ROOMDG 1A DAY TANK ROOMDG 1 B DAY TANK ROOMDG 1 C DAY TANK ROOMDG 1A ENGINE ROOMDG lB ENGINE ROOMDG 1C ENGINE ROOMDG 1A SWGR ROOMDG 1B SWGR ROOMLDG lC SWGR ROOMPREFIRE PLANDWG #A-43966A-43966A-43966A-43 966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SHT #5A, B15A,B11A,B7A,B1 4A, B10A, B6A, B16A, B12A, B8A,B1 7A, B13A, B9A, B1 and 221 and 2121 and 21221221PROTECTEDSAFE SHUTDOWNPATHYARDCOOLING TOWERSINTAKE STRUCTUREPLANT SERVICE WATER VALVE PIT 2APLANT SERVICE WATER VALVE PIT 2BCONDENSATE STORAGE TANK AREANITROGEN STORAGE TANK AREATRANSFORMERSAUXILIARY BOILERCIRC WATER PUMP PITFIRE PROTECTION PUMP HOUSE,WEST AREAA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396674A, B thru 76C,D27A, B50A, B51A,B43A,B41 A, B56A, B61A,B52A,B46A,B1 and 21 and 221111 and 2NA21 and 2 V20Page 6 of 20SNC LANTE. I HATH IPg 88 of 118DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-00 1-1 13.1ATTACHMENT 2_ Attachment PageTITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 4 OF 5REACTOR BUILDINGPREFIRE PLANDWG #PROTECTEDSAFE SHUTDOWNPATHSHT #51A,BDIV I RHR AND CORE SPRAY SECORNER ROOMDIV II RHR AND CORE SPRAY NECORNER ROOMCRD CORNER ROOMRCIC ROOMHPCI ROOMTORUS ROOM -SOUTH HALFTORUS ROOM -NORTH HALF130 FT ELEV -SOUTH130 FT ELEV -NORTHREClRC ASD ROOM 1ARECIRC ASD ROOM lBRWCU PUMP A ROOMRWCU PUMP B ROOM158 ELEV -WORKING FLOORDECANT PUMP ROOM164 FT ELEV HVAC ROOMFUEL POOL COOLING AREA SR-1205RRWCU EQUIPMENT AND SAMPLING ROOMSSUPPLY FAN ROOM185 FT WORKING FLOORTURBINE BUILDING EXHAUST FILTER ROOMSBGT ROOM203 FT WORKING FLOOR203 FT REFUELING AIR SUPPLY ROOM228 FT REFUELING FLOORDRYWELL AND TORUSA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965253A,B 154A, B 152A,B 255A,B 156A, B 257A,B 158A,B 259A,B 163A,B 264A,B 1 and 262A,B 162A,B 161A,B 161A,B 165A,B 167A,B 169A,B 169A,B 168A,B; 67A,B 171A,B 166A,B 173A,B 173A,B 174A,B 1 and 256A,B & 1 and 257A,B(Torus Room Only)PROTECTEDSAFE SHUTDOWNSHT # PATHPREFIRE PLANDWG #TURBINE BUILDINGEAST CABLEWAYTURBINE BUILDINGWEST CABLEWAYTURBINE DECKSTAIRWAYSEAST CABLEWAY FOYERA-43965A-43965A-43965A-43965A-43965A-4396534A,BN/A81A,B87A,B, 88A, BN/A34A, B122222 V20Page 7 of 20SNC LAN E.I. HTCHI IPg 90 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 3_ Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 1 1 OF 81.0 PATHWAY 1 TO SHUTDOWNSystems Required1.1.1 RHR, Pump A; RHR Service Water Pump A.1.1.2 RClC1.1.3 SRVs, Gand H1.1.4 Plant Service Water, Pump A1.1.5 RHR and RClC Emergency Room Ventilation System, A Coolers1.1.6 RPV Instrumentation1.1.7 Containment Instrumentation1.1.8 Drywell Air Supply1.1.9 Diesel Generator and Associated Electrical Equipment1.1.10 MSIVs1.1.11 Diesel Building Ventilation1.1.12 Intake Structure Ventilation V20Page 8 of 20SNC LAN E.I. HTCHI lPg 98 of 118DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FI RE PROCEDURE 34AB-X43-001 -1 13.1ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 2 1 OF 82.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR System, Pump B; RHR Service Water Pump B.2.2.2 RHR and HPCI Room Coolers, B Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air2.2.7 Diesel Generator and Associated Electrical Equipment2.2.8 HPCI2.2.9 Core Spray (for Fire Area 1203 only)2.2.10 SRVs, A and C.2.2.11 MSIVs2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 9 of 20SNC LANTE. I HATH IPg 106 of 118DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-1 13.1ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 3 I OF 83.0 PATHWAY 3 TO SHUTDOWN3.1 Systems Required3.2.1. RHR System, Pump B; RHR Service Water Pump B3.2.2. RHR and RCIC Room Coolers3.2.3. Plant Service Water, Pumps A and B.3.2.4. RPV Instrumentation3.2.5. Containment Instrumentation3.2.6. Drywell Air3.2.7. Diesel Generator and Associated Electrical Equipment3.2.8. RCIC3.2.9. SRVs, C and G.3.2.10. MSIVs3.2.11. Diesel Building Ventilation3.2.12. Intake Structure Ventilation V20Page 10 of 20SOUTERNNUCEAR I DOUMET TPE:PAGEPLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 114DOCUENTTITL: IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-00 1-2 15.0EXPIATIN APROVLS:EFFECTIVEDATE: DEPARTMENT MGR Daniel A. Komm DATE 3-18-15 DATE:N/A SS M/PM N/A DATE N/A 3-18-2015TABLE OF CONTENTSSection Page1.0 CONDITIONS..................................................................................... 32.0 AUTOMATIC ACTIONS.......................................................................... 33.0 IMMEDIATE OPERATOR ACTIONS ............................................................ 34.0 SUBSEQUENT OPERATOR ACTIONS......................................................... 45.0 CONTROL BUILDING............................................................................ 75.1 Control Building Ventilation Fans............................................................ 75.2 Ventilation Restoration....................................................................... 75.3 Control Building Specific Area Actions...................................................... 85.4 Oil Storage Tank Room ...................................................................... 85.5 Station Battery Rooms (FA 2005) ........................................................... 85.6 RPS Battery Rooms.......................................................................... 85.7 130 ft elev. Passageways, HVAC Room and Lab .......................................... 85.8 Annunciator Room ........................................................................... 95.9 Oil Conditioner Room (FA 2023) ............................................................ 95.10 RPS MG Set Room and Vertical Cableway................................................. 95.11 DC Switchgear Rooms....................................................................... 95.12 Switchgear Access Hallway & 600V Switchgear Room 2C............................... 105.13 600V Switchgear Room 2D................................................................. 115.14 Transformer Room 2CD .................................................................... 125.15 Main Control Room, Cable Spreading Room or Computer Room ....................... 135.16 Control Building 112 ft Elevation Working Floor, Corridor, and Annunciator Logic Cabinet(FA 0001).................................................................................... 145.17 Water Analysis Room (FA 2006)........................................................... 146.0 DIESEL GENERATOR BUILDING............................................................. 156.1 Diesel generator Building Specific Area Index ............................................ 156.2 DG Battery Rooms.......................................................................... 156.3 DG Day Tank Rooms ....................................................................... 166.4 DG Engine Rooms.......................................................................... 186.5 DG 2A Swgr Room 2E (2R22-S005) ...................................................... 196.6 DG 1B Swgr Room 2F (2R22-S006) ...................................................... 206.7 DG 2C Swgr Room 2G (2R22-S007) ...................................................... 217.0 YARD ............................................................................................ 227.1 Plant Yard Specific Area Index............................................................. 227.2 Intake Structure ............................................................................. 227.3 Nitrogen Storage Tank AREA.............................................................. 23 V20Page 11 of 20PAGE2 OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCMEN TILE:DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.07.4 Main or Unit Auxiliary Transformer......................................................... 237.5 Startup Auxiliary Transformer .............................................................. 237.6 Auxiliary Boiler .............................................................................. 237.7 Waste Gas Treatment Building....................,......................................... 237.8 High Voltage Switchyard ................................................................... 237.9 Circulating Water Pump Pit ................................................................ 238.0 REACTOR BUILDING .......................................................................... 248.1 Reactor Building Ventilation................................................................ 248.2 Reactor Building Specific Area Index...................................................... 248.3 North Half of Reactor Building Below 185 ft ............................................... 258.4 ASD Rooms ................................................................................. 278.5 South Half of Reactor Building, and All of the 185 ft and 203 ft Elevations ............. 288.6 Drywell....................................................................................... 389.0 TURBINE BUILDING ........................................................................... 399.1 Turbine Building Specific Area Index ...................................................... 399.2 Turbine Building............................................................................. 399.3 Turbine Building Unit 2 East Cableway (2104)............................................ 409.4 Turbine Building East Cableway Foyer .................................................... 409.5 Turbine Building Unit 1 East Cableway.................................................... 4110.0 RADWASTE BUILDING ....................................................................... 4210.1 Ventilation Charcoal Filter trains ........................................................... 4211.0 RECORDS ..................................................................................... 4312.0 COMMITMENTS............................................................................... 43Attachments1 SAFE SHUTDOWN ACTIONS ................................................................. 442 PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 ................................ 853 SAFE SHUTDOWN PATHS FOR UNIT 2 FOR UNIT 1 FIRES .............................. 894 SAFE SHUTDOWN COMPONENT LIST PATH 1I............................................ 905 SAFE SHUTDOWN COMPONENT LIST PATH 2 ............................................ 966 SAFE SHUTDOWN COMPONENT LIST PATH 3 ........................................... 1037 LINKS NORMALLY OPEN TO SUPPORT APPENDIX R ................................... 1108 REFERENCE DRAWINGS LIST.............................................................. 1119 PLACARDS FOR 2H11-P601................................................................. 11310 KEY MILESTONES FORA FIRE OR FIRE DRILL .......................................... 114 V20Page 12 of 20SOUTERN UCLER IPAGEPLAN E. .HACHJ250OF 114DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001 -2 15.08.3 NORTH HALF OF REACTOR BUILDING BELOW 185 FT. ELEVATION8.3.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.3. LII8.3.2 This fire area consists of the following fire zones, perform the steps applicable to the area:STEP ZONE PAGE8.3.3 North Half of Torus Room ............................................................ 258.3.4 RCIC Corner Room ................................................................... 258.3.5 Div I RHR and Core Spray Corner Room............................................ 268.3.6 130 Ft Elevation, North Half.......................................................... 26Reactor Building Stairwell NO ACTIONS *158 Ft Elevation, North Half NO ACTIONS ** No additional actions are required beyond normal fire response actions.8.3.3 North Half of Torus Room8.3.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. Eli8.3.4 RClC Corner Room8.3.4.1 Stop RClC Pump Rm Coolers.* 2T41-B004A El* 2T41-B004B El8.3.4.2 Close RClC Steam Supply Isol AND Steam Supply Line Isol Valves.* 2E51-F007 El* 2E51-F008 El V20Page 13 of 20PAGE280OF 114SOUTHERN NUCLEARPLANT E. I. HATCHDOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO:FIRE PROCEDURE 34AB-X43-001-2 15.08.5 SOUTH HALF OF REACTOR BUILDING, AND ALL OF THE 185 FT AND 203 FTELEVATIONS8.5.1 IF a reactor SCRAM has occurred,perform safe shutdown actions listed in Attachment 1, Step 8.5. LI8.5.2 This fire area consists of the following fire zones,perform the steps applicable to the fire zone: LISTEP ZONE PAGE8.5.3 South Half of Torus Room........... ............................................... 278.5.4 CRD Corner Room.................................................................. 288.5.5 Div II RHR and Core Spray Corner Room (Southeast) ........................... 298.5.6 HPCI Room.......................................................................... 298.5.7 130 Ft Elevation, South Half........................................................ 308.5.8 158 Ft. Elevation South Half........................................................ 308.5.9 164 Ft HVAC Room................................................................. 318.5.10 Fuel Pool Cooling And Heat Exchanger Room.................................... 328.5.11 Fuel Pool and RWCU Precoat Equipment Area................................... 328.5.12 185 Ft Elevation Working Floor .................................................... 338.5.13 185 Ft HVAC Room................................................................. 348.5.14 Standby Gas Treatment Room..................................................... 348.5.15 203 Ft Working Floor................................................................ 358.5.16 203 Ft HVAC Room................................................................. 358.5.3 South Half of Torus Room8.5.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. L[]
+V20Page 14 of 20SNC LAN E.I. HTCHI I Pg 85 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 1 OF 4*The Safe Shutdown Paths listed indicate the Safe Shutdown Train that has been analyzed for a firein the associated area. The Safe Shutdown Path (1 OR 2) least impacted by the fire in each areawas identified AND analyzed. It is assumed that only one path is available for shutdown for thepurpose of engineering analysis. This does NOT prevent Operator use of systems outside of theanalyzed path IFE they continue to function as required. For fire areas where protection of one pathCANNOT be achieved, such as the Main Control Room, Cable Spreading Room AND ComputerRoom, Remote Shutdown Systems (Path 3) were identified AND~. analyzed.* Where circuit failures to analyzed path components can be compensated for by a manual operatoraction, those actions are contained in this procedure.*The components that are analyzed WITHIN each Safe Shutdown Path, as determined below, aregiven in Attachment 4 (Path 1), Attachment 5 (Path 2) AND Attachment 6 (Path 3 -RemoteShutdown). These component lists are to be considered the minimum equipment that will survive ina given fire area. Other equipment, may survive the fire. Circuit faults to unanalyzed equipmenthave NOT been evaluated.
+V20Page 15 of 20SNC LANTE. I HATH IPg 86 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 2 OF 4ANALYZEDPREFIRE PLAN SAFE SHUTDOWNCONTROL BUILDING DWG # SliT# PATH112 Ft Elev Passageways, Hot Instrument Shop A-43965 5A, B 2and Service Air Compressor RoomsOil Storage Tank Room A-43965 1 6A, B 1 and 2Freight Elevator or Stairway A-43965 6A, B 2Station Battery Room 2A A-43965 1 7A, B 2Station Battery Room 2B A-43965 1 8A, B 1AC Inverter Room A-43965 20A, B 1 and 2RPS Battery Room 2A A-43965 21A, B 1 and 2RPS Battery Room 2B A-43965 22A, B 1 and 2Water Analysis Room A-43965 1 9A, B 1Unit 2 130 Ft Elev Switchgear Hallway A-43965 24A, B 2Switchgear Hallway Enclosure A-43965 35A, B 2All Other 130 Ft Elev Passageways A-43965 24A, B 2HVAC Room -130 Ft Elev A-43965 25A, B 2RPS MG Room A-43965 26A, B 1Vertical Cable Chase A-43965 26A, B 2Annunciator Room A-43965 36A, B 2Oil Conditioner Room A-43965 42A, B 2DC SWGR Room 2A A-43965 39A, B 2DC SWGR Room 2B A-43965 41A, B 1Rad Protection Area and Radwaste Lab A-43965 23A, B 2600V SWGR Room 2C A-43965 37A, B 2I600OV SWGR Room 2D A-43965 38A, B 12CD Transformer Room A-43965 40A, B 1CO2 Storage Tank Area A-43965 46A, B 2LPCI Inverter Room A-43965 47A, B 2Main Control Room A-43965 48A, B 3Cable Spreading Room A-43965 44A, B 3Computer Room A-43965 45A, B 3Control Room Roof A-43965 50A, B 2Control Bldg East Corridor, Cold Lab, and A-43965 7A, B 2Adjacent Rooms, El 112 9A, BSwitchgear Access Hallway A-43965 35A, B 1 V20Page 16 of 20SNC LANTE. I HATH IPg 87 of 114DOUMNTTILE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001 -2 15.0ATTACHMENT 2 Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 3 OF 4DIESEL GENERATOR BUILDINGDG Building HallwayDG 2A Battery RoomDG 1 B Battery RoomDG 2C Battery RoomDG 2A Day Tank RoomDG 1 B Day Tank RoomDG 2C Day Tank RoomDG 2A Engine RoomDG 1B Engine RoomDG 2C Engine RoomDG 2A SWGR Room 2EDG lB SWGR Room 2FDG 2C SWGR Room 2GPREFIRE PLANDWG #A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966SliT#5A, B19A, B11A, B23A, B18A, B10A, B22A, B20A, B12A, B24A, B21A, B25A, B26A, BANALYZEDSAFE SHUTDOWNPATH1 and 221 and 2121 and 2121 and 21221YARDCooling TowersIntake StructurePlant Service Water Valve Pit 2APlant Service Water Valve Pit 2BCondensate Storage Tank AreaNitrogen Storage Tank Area500KV Reactor SwitchyardMain 500 KV SwitchyardAuxiliary BoilerCirc Water Pump PITRadwaste Dilution Valve PitDiesel 2A Fuel Oil Storage TankDiesel 20 Fuel Oil Storage TankA-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-43966A-4396677A, B79A, B, C, D27A, B50A, B51A, B44A, B42A, B84A, B82A, B61A, B53A, B59A, B73A, B73A, B1 and 21 and 22121 and 21 and 22N/A2221 V20Page 17 of 20SNC LAN E.I. HTCHI IPg 88 of 114DOCMEN TTLE IDOCUMENT NUMBER:I Version No:FIRE PROCEDURE 34AB-X43-00 1-2 J 15.0ATTACHMENT 2_ Attachment PageTITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 J 4 OF 4PREFIRE PLANDWG #ANALYZEDSAFE SHUTDOWNPATHREACTOR BUILDINGSHT#Div I RHR and Core Spray NE Corner RoomDiv II RHR and Core Spray SE Corner RoomCRD Corner RoomRClC RoomHPCI RoomTorus Room -South HalfTorus Room -North Half130 Ft Elev -South130 Ft Elev -NorthRecirc ASD Room 2ARecirc ASD Room 2BRWCU Pump A RoomRWCU Pump B Room158 Elev South -Working Floor158 Elev North164 Ft Elev HVAC RoomFuel Pool Cooling Heat ExchangerFuel Pool and RWCU Precoat Equip Area185 Ft Supply Fan Room185 Ft Working Floor185 Ft HVAC RoomSBGT Room ASBGT Room B203 Ft Elevation203 Ft ElevationRefuel FloorDrywellA-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-43965A-4396599A, B 2101AB 1102AB 1100A.,B 2103A.,B 1105A. B 1104AB 2107AB 1106A, B 2113A, B 1land 2114A, B 1land 2111A, B 1111A, B 1110A, B 1109A, B 2112A, B 1116A, B 1116A, B 1118A, B 1116A, B117A,B 1118AB 1115A, B 1115A, B 1122A, B 1120A,B 121A,B 1123A, B 1land 2104A,B 105A,B 1 and 2(Torus Area Only)108A, B 1Main Steam ChaseTURBINE BUILDINGTurbine Bldg Fire Area 2101164 Ft Elev Turbine Deckand other Fire Area 0101Turbine Building Below Turbine DeckWest CablewayStairwaysTurbine DeckEast CablewayA-43965A-4396549A, B 87-90A, BA-43965A-43965A-43965A-43965A-43965124-1 32A,133-1 36A,N/A128A, BN/A134A, B43A, BBB2122221 V20Page 18 of 20SNC LANTE. I HATH 1Pg 90 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDUREI 34AB-X43-001-2 15.0ATTACHMENT 4 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 1 1 OF 61.0 PATHWAY I TO SHUTDOWN1.1 Systems Required1.2.1 RHR, Pump A, RHR Service Water Pump A1.2.2 RCIC1.2.3 SRVs1.2.4 Plant Service Water, Pump A1.2.5 Emergency Room Coolers1.2.6 RPV Instrumentation1.2.7 Containment Instrumentation1.2.8 Drywell Air (Nitrogen System, Drywell Pneumatic System)1.2.9 Diesel Generator 2A and Associated Electrical Equipment1.2.10 MSIVs, Inboard1.2.11 Core Spray Loop A (for spurious ADS WHEN RHR Loop "A" NOT available)1.2.12 Diesel Building Ventilation1.2.13 Intake Structure Ventilation1.2 System Components1.2.1 RHR, Pump A and RHR Service Water, Pump ARequiredNormal PATH 1MPL No Mode SSD Mode2E11-C001A OFF ON2E11-C002A OFF ON2E11-F003A 0 02E 11-F004A 0 02E11-F006A C C2E11-F007A 0 VAR2E1l-F010 C C2E11-F011A C C2E11-F015A C 02E11-F016A C C2E11-F017A 0 02E11-F026A C C2E11-F028A C C2E11-F047A 0 02E11-F048A 0 VAR2E11-F065A 0 0RequiredNormal PATH 1MPL No Mod._._e SSD Mode2E11-F068A C VAR2E11-F073A C C2E1 1-F104A C C2E11-F119A C C2E11-K600A ON ON2E11-K603A ON ON2E11-N007A ON ON2E11-N015A ON ON2E11-N017A C 02E11-N017C C 02E11-N082A ON ON2E11-N104A ON ON2E11-N682A C VAR2E11-R600A ON ON2E11-R602A ON ON2E11-R603A ON ON V20Page 19 of 20SNC LANTE. I HATH IPg 96 of 114DOCMEN TTLE IDOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 5 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 2 I OF 72.0 PATHWAY 2 TO SHUTDOWN2.1 Systems Required2.2.1 RHR, Pump B, RHR Service Water Pump B2.2.2 Emergency Room Coolers2.2.3 Plant Service Water, Pump B2.2.4 RPV Instrumentation2.2.5 Containment Instrumentation2.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)2.2.7 HPCI2.2.8 Diesel Generator 2C and Associated Electrical Equipment2.2.9 Core Spray, Loop B (for spurious ADS WHEN RHR Loop "B" NOT[ available)2.2.10 SRVs2.2.11 MSIVs, Outboard2.2.12 Diesel Building Ventilation2.2.13 Intake Structure Ventilation V20Page 20 of 20SNC LANTE. I HATH IPg 103 of 114DOCMET ITE:DOCUMENT NUMBER: Version No:FIRE PROCEDURE 34AB-X43-001-2 15.0ATTACHMENT 6 Attachment PageTITLE: SAFE SHUTDOWN COMPONENT LIST PATH 3 1OF 73.0 PATHWAY 3 TO SHUTDOWN (REMOTE SHUTDOWN SYSTEMS)3.1 Systems Required3.2.1 RHR, Pump B, RHR Service Water Pump B3.2.2 Emergency Room Coolers3.2.3 Plant Service Water, Pump B3.2.4 RPV Instrumentation3.2.5 Containment Instrumentation3.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)3.2.7 RCIC3.2.8 Diesel Generators 2A and 2C and Associated Electrical Equipment3.2.9 SRVs3.2.10 MSIVs, Inboard3.2.11 Diesel Building Ventilation3.2.12 Intake Structure Ventilation V21Page 1 of 14. ITheMinmumSteam Cooling RPV Water Level for Hatch is: -180 inches. (Both5. The Minimum Steam Cooling RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. The temperature of the water injected into the RPV is 1 000F.6. Plant-specific data required to calculate the Minimum Steam Cooling RPV WaterLevel is as follows:a. Minimum active fuel length fraction which must be covered to maintain peakclad temperature below 1 5000F with injection.b. Active fuel lengthc. Water level at the bottom of the active fuelE. Minimum Zero-Injection RPV Water Level(LT 31) (LCT 31)1. The Minimum Zero-Injection RPV Water Level is defined to be the lowest RPVwater level at which the covered portion of the Reactor core will generate sufficientsteam to preclude any clad temperature in the uncovered portion of the core formexceeding 1 8000F. This Water Level is utilized to preclude significant fuel damageand hydrogen generation for as long as possible.2. This is the level at which Steam Cooling Without injection is used in the EOPs.A cold shutdown rod configuration must exist to use this core cooling method.3. The Minimum Zero-Injection RPV Water Level for Hatch is: -195 inches.(Both units)4. The Minimum Zero-Injection RPV Water Level is determined assuming:a. The Reactor has been shut down from rated power for 10 minutes.b. The Reactor axial power shape was the most limiting top-peaked power shapeprior to Reactor shutdown.c. No water is injected into the RPV.EOP-CURVES-LP-20306 Ver 3.0 GRAPH 2V22Page 1 of 2UNIT 1HEAT CAPACITY TEMPERATURE LIMIT0[-(i-TORUS WATER LEVEL (in)NOTE: May use SPDS Emergency Displays in place of this Graph.* Safe operating is below the applicable pressure line.
+V22Page 2 of 2SGRAPH 2Heat Capacity Temperature LimitEI-2602402202O00180160140120._'C')I..'IC')0Ra-x.I8098 120 140 160 180193200Torus Water Level (in)Note: May use SPDS in place of this GraphREQUIRED if above curve for existing RPV pressEOP-CURVES-20306FIG 2Page 61 of 75 V23Page 1 of 4Mare Condenser Offgas3.7.63.7 PLANT SYSTEMS3.7.6 Main Condenser OffgasLCO 3.7.6tiT e gross gamma actvity rate of the noble gases measured at the maincondenser evacuation system pretreatmentl monitor station shall be240 mCi/seond. ,MODE 1,MODES 2 and 3 with any main steam line not isolated and steam jet airejector (SJAE) in operation.APPLICABILITY:ACTIONS___________ _____ ___CONDITION REOUIRED ACTION COMPL=ETION TIMEA. Gross gamma activity rate A.1 Restore gross gamma 72 hoursof the noble gases not activity rate of the noblewithin limit, gases to limit.B8 Required Action and B. 1 Isolate all main steam 12 hoursassociated Completion linesTime not met.OR8.2 Isolate SJAE 12 hoursORRB.3.1 Be in MODE 3 12 hoursANDB,3.2 Be in MODE 4. 36 hootsHATCH UNIT 23.7-16HATC UNI 2 37-16Amendment No. 135 CDCD0(0CDN, 0-9CD V23, Page 4 of 4SU3 Reactor coolant activity greater than Technical Specification allowable limits.Operating Mode:Power OperationStartupHot StandbyHot Shutdown(1 OR 2)Emergency Action Levels:1. Pretreatment Radiation Monitor reading greater than 240,000 pCi/sec for greater than60 minutes.According to Tech. Spec. Bases 3. 7.6 page B3. 7-31 and Tech. Spec. section 3. 7.6page 3. 7-16, the gross gamma activity rate of the noble gases measured at the maincondenser evacuation system pretreatment monitor station shall be <.240mCi/secondor <240, O00pCifsecond. According to 64C1-0CB-006-1/2 procedures the offgaspretreatment radiation monitors are 1/2D1 1-K601 and 1/2D1 1-K602OR2. Sample analysis indicates that the reactor coolant specific activity is EITHER:* Greater than 0.2 pCi/gm and less than or equal to 2.0 pCi/gm doseequivalent 1131 for greater than 48 hours.* Greater than 2.0 pCi/gm dose equivalent 1131.According to Tech. Spec. Bases 3. 4.6 page B3.4-25 and Tech. Spec. section 3. 4.6page 3.4-11, the specific activity of the reactor coolant shall be limited to DOSEEQUIVALENT 1-131 specific activity 0.2 IJCi/gm. A condition >0.2 pCi/gm but <2.OIJCi/gm must be restored within 48 hours. A condition > 2pCi/gm requires immediateaction, V24Page 1 of 1RCS Specifi Activity3.4.63.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 RCS Specific ActivityLCO 3.4.6Thre specifi activty of the reactor coolant shag be limited to DOSEEQUIVALEFNT 1-131 speific activit 0.2 pC~igm.APUCBIUTrY:MODE 1,MODS 2 and 3 with any m'aui steam line not isolated.ACTIONSCO,,NDmON REQUIRED ACTION COMPLETION TIMEA.Reacto colaspecifi NOTESacbvtty 0.2 &aCim and LCO 3.0.4.c is apl:iicable.1 2.0 DOSElEQUIVALENT 1-131.A.1 Determine DOSE Once per 4 hoursEQUIVALENT 1-131.ANDA.2 Restore DOSEEQUIALENT 1-131 toB. Required Ac~tion an B.1 Determine DOSE Once per 4 hoursassociated Completion EQUIVALENT 1-131.Time of Cocst A notQR B2.1 Isolate all main steam 12 hoursReactor coolant spciiactivity >2.0 DOSE OEQUIVALENT 1-131.B22.1 BeminMODE 3. 12 IurS8222 Be in MODE 4. 36 hoursHATCH UNIT 23.4-11HATH UIT 34-1 AmndmntNo. 210 V25Page 1 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (Refs. 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation and thecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 1 .-3RVSOB 3.4-13REVISION 0 V25Page 2 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment canI(continued)HATCH UNIT 1 B341 EIIN5B 3.4-14REVISION 59 V25Page 3 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._IWith RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 1 .-5RVSOB 3.4-15REVISION 0 V25Page 4 of 6RCS Operational LEAKAGEB 3.4.4B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGEBASESBACKGROUND The RCS includes systems and components that contain or transportthe coolant to or from the reactor core. The pressure containingcomponents of the RCS and the portions of connecting systems out toand including the isolation valves define the reactor coolant pressureboundary (RCPB). The joints of the RCPB components are welded orbolted.During plant life, the joint and valve interfaces can produce varyingamounts of reactor coolant LEAKAGE, through either normaloperational wear or mechanical deterioration. Limits on RCSoperational LEAKAGE are required to ensure appropriate action istaken before the integrity of the RCPB is impaired. This LCOspecifies the types and limits of LEAKAGE. This protects the RCSpressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), andGDC 55 of 10 CFR 50, Appendix A (References 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varieswidely depending on the source, rate, and duration. Therefore,detection of LEAKAGE in the primary containment is necessary.Methods for quickly separating the identified LEAKAGE from theunidentified LEAKAGE are necessary to provide the operatorsquantitative information to permit them to take corrective action shoulda leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expectedfrom auxiliary systems that cannot be made 100% leaktight. Leakagefrom these systems should be detected and isolated from the primarycontainment atmosphere, if possible, so as not to mask RCSoperational LEAKAGE detection.This LCO deals with protection of the RCPB from degradation andthecore from inadequate cooling, in addition to preventing the accidentanalyses radiation release assumptions from being exceeded. Theconsequences of violating this LCO include the possibility of a loss ofcoolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on theSAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. Thenormally expected background LEAKAGE due to equipment design(continued)HATCH UNIT 2 B341 EIIN7B 3.4-14REVISION 77 I V25Page 5 of 6RCS Operational LEAKAGEB 3.4.4BASESAPPLICABLE and the detection capability of the instrumentation for determiningSAFETY ANALYSES system LEAKAGE were also considered. The evidence from(continued) experiments suggests that, for LEAKAGE even greater than thespecified unidentified LEAKAGE limits, the probability is small that theimperfection or crack associated with such LEAKAGE would growrapidly.The unidentified LEAKAGE flow limit allows time for corrective actionbefore the RCPB could be significantly compromised. The 5 gpm limitis a small fraction of the calculated flow from a critical crack in theprimary system piping. Crack behavior from experimental programs(Refs. 4 and 5) shows that leakage rates of hundreds of gallons perminute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failuremechanism of intergranular stress corrosion cracking (IGSCC) thatproduces tight cracks. This flow increase limit is capable of providingan early warning of such deterioration.No applicable safety analysis assumes the total LEAKAGE limit. Thetotal LEAKAGE limit considers RCS inventory makeup capability anddrywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC PolicyStatement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to:a. Pressure Boundary LEAKAGENo pressure boundary LEAKAGE is allowed, being indicativeof material degradation. LEAKAGE of this type isunacceptable as the leak itself could cause furtherdeterioration, resulting in higher LEAKAGE. Violation of thisLCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundaryLEAKAGE.b. Unidentified LEAKAGEThe 5 gpm of unidentified LEAKAGE is allowed as a reasonableminimum detectable amount that the containment air monitoringand drywell sump level monitoring equipment can(continued)HATCH UNIT 2 B341 EIIN7B 3.4-15REVISION 77 I V25Page 6 of 6RCS Operational LEAKAGEB 3.4.4BASESLCOLCOb. Unidentified LEAKAGE (continued)detect within a reasonable time period. Violation of this LCOcould result in continued degradation of the RCPB.c. Total LEAKAGEThe total LEAKAGE limit is based on a reasonable minimumdetectable amount. The limit also accounts for LEAKAGEfrom known sources (identified LEAKAGE). Violation of thisLCO indicates an unexpected amount of LEAKAGE and,therefore, could indicate new or additional degradation in' anRCPB component or system.d. Unidentified LEAKAGE IncreaseAn unidentified LEAKAGE increase of > 2 gpm within theprevious 24 hour period indicates a potential flaw in the RCPBand must be quickly evaluated to determine the source andextent of the LEAKAGE. The increase is measured relative tothe steady state value; temporary changes in LEAKAGE rateas a result of transient conditions (e.g., startup) are notconsidered. As such, the 2 gpm increase limit is onlyapplicable in MODE 1 when operating pressures andtemperatures are established. Violation of this LCO couldresult in continued degradation of the RCPB.APPLICABILITY In MODES 1, 2, and 3, the RCS operational LEAKAGE LCO applies,because the potential for RCPB LEAKAGE is greatest when thereactor is pressurized.In MODES 4 and 5, RCS operational LEAKAGE limits are notrequired since the reactor is not pressurized and stresses in theRCPB materials and potential for LEAKAGE are reduced.ACTIONS A._1!With RCS unidentified or total LEAKAGE greater than the limits,actions must be taken to reduce the leak. Because the LEAKAGElimits are conservatively below the LEAKAGE that would constitute acritical crack size, 4 hours is allowed to reduce the LEAKAGE ratesbefore the reactor must be shut down. If an unidentified LEAKAGE(continued)HATCH UNIT 28341REION7B 3.4-16REVISION 77}}

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