Text

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 8 Page 1 of 10 SOUTHERN NUCLEARI PLANT El. HATCH PAGE 9 OF 30 DOUMNTTILE t DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAINMENT CONTROL t 34AB-T22-003-1 5.14 ATTACHMENT 2 ATT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1G31-R604) 1 OF 1 Max Normal Max Safe SECONDARY CONTAINMENT TEMP Operating Operating on 1H11-P614, 1G31-R604 Value Value 0 F o 158' ELEVATION AREA (RWCU)101 B Pump Room (1G31-N016D) 150 212.5 102 B Pump Room DIFF (1G31-N022C/1G31-N023C) 67 98 103 Hx Room (1G31-N016B) 150 212.5 104 Hx Room DIFF (1G31-N022D/1G31-N023D) 67 98 105 Ph Sep Rm (1G31-N016F) 150 212.5 106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98 NORTHEAST DIAGONAL AREA 107 RHR/CS B (1E11-N009B) 150 212.5 108 RHR/CS B DIFF(1E11-N030B/1E11-N029B) 40 98 HPCl ROOM AREA 109 Emer Area CIr (1E41-N030B) 167.5 245 110 HPCI VENT AIR DIFF (1E41-N029B/1E41-N028B)

NA NA (not used)RCIC ROOM AREA 111 Emer Area CIr (1 E5I-N023B) 167.5 310 112 RCIC VENT AIR DIFF (1E51-N022B/1E51-N021 B) NA NA (not used)TORUS ROOM AREA 113 Southwest Wall (1E51-N025B) 167.5 212.5 114 Northeast Wall (1E51-N025D) 167.5 212.5 115 VENT AIR DIFF (1E51-N027B/1E51-N026B) 42 102 116 VENT AIR DIFF (1 E51-N027D/1 E51-N026D) 42 102 HPCI PIPE PENETRATION ROOM 117 1E41-N046B 150 212.5 Posted 1 H11-P614 MGR-0009 Rev 5.0 V1 8 Page 2 of 10 PAGE 10 OF 30 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-1 5.14 ATTACHMENT 3 ATTACH. PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1 G31 -R608) 1 OF 1 Max Normal Max Safe SECONDARY CONTAINMENT TEMP Operating Operating on 1IH11-P614, 1G31-R608 Value Value oF o 158' ELEVATION AREA (RWGU)101 A Pump Room (1G31-N016C) 150 212.5 102 A Pump Room DIFF (1G31-N022B/1G31-N023B) 67 98 103 Hx Room (1G31-N016E) 150 212.5 104 Hx Room DIFF (1G31-N022A/1G31-N023A) 67 98 105 Phase Sep Rm (1G31-N016A) 150 212.5 106 Phase Sep Rm DIFF (1G31-N022E/1G31-N023E) 67 98 SOUTHEAST DIAGONAL AREA 107 RHR/CS A (lE1 1-N009A) 150 212.5 108 RHRICS A DIFF (1EI11-N030A/1 E11-N029A) 40 98 HPCI ROOM AREA 109 Pump Room (1E41-N024) 167.5 245 110 Emer Area CIr (1 E41 -N030A) 167.5 245 111 HPCl VENT AIR DIFF (1 E41-N029A/11E41-N028A)

NA NA (not used)_________

RClC ROOM AREA 112 Pump Room (1E51-N011) 167.5 310 113 Emer Area CIr (1E51-N023A) 167.5 310 114 RCIC VENT AIR DIFF (1 E51-N022A/1 E51-N021A)

NA NA (not used)TORUS ROOM AREA 115 West Wall (1E51-N025A) 167.5 212.5 116 Southeast Wall (1E51-N025C) 167.5 212.5 117 VENT AIR DIFF (1 E51-NO26AI1 E51-N027A) 42 102 118 VENT AIR DIFF (1E51-N026C/1 E51-N027C) 42 102 MAIN STEAM LINE TUNNEL AREA 119 Main Stm TnI 1B21-N014 192.5 300 120 1B21-N016AN0O16B DIFF 60 150 HPCI PIPE PENETRATION ROOM 150 212.5 121 1E41-N046A Posted 1 H11-P614 MGR-0009 Rev 5.0 V1 8 Page 3 of 10 PAGE 27 OF 30 SOUTHERN NUCLEAR PLANT E.I. HATCH DOUMNTTILE

]DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14 ATTACHMENT 9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2 Max Max SECONDARY CONTAINMENT TEMPNoml Sf on IHI1-P614, 1G31-R604 0 158' ELEVATION AREA (RWCU)101 B Pump Rm (1G31-N016D) 150 212.5 102 B Pump Rm DIFF (1G31-N022C/1G31-N023C) 67 98 103 Hx Rm (1G31-N016B) 150 212.5 104 Hx Rm DIFF (1G31-N022D/1G31-N023D) 67 98 105 Ph Sep Rm (1G31-N016F) 150 212.5 106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98 NORTHEAST DIAGONAL AREA 107 RHR/CS B(1E11-N009B) 150 212.5 108 RHR/CS B DIFF (1E11-N030B/1E11-N029B) 40 98 HPCI ROOM AREA 109 Emer Area CIr (1E41-N030B) 167.5 245 RCIC ROOM AREA 111 Emer Area Clr (1 E51-N023B) 167.5 310 TORUS ROOM AREA 113 Southwest Wall (1E51-N025B) 167.5 212.5 114 Northeast Wall (1 E51-N025D) 167.5 212.5 115 Vent Air DIFF (1E51-N027B/1E51-N026B) 42 102 116 Vent Air DIFF (1E51-N027D/1E51-N026D) 42 102 HPCl PIPE PENETRATION ROOM 117 1E41-N046B 150 212.5 RDG RDG 1 2 3 Reference 34AB-T22-003-1 MGR-0009 Rev 5.0 Vi18 Page 4 of 10 PAGE 28 OF 30 SOUTHERN NUCLEARI PLANT E.I. HATCH DOUMNTTILE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14 ATTACHMENT

-9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2 SECONDARY CONTAINMENT TEMP Max Max on 1H11-P614, 1G31-R608 Normal Safe 158' ELEVATION AREA (RWCU)101 A Pump Rm (1G31-N016C) 150 212 102 A Pump Rm DIFF (1G31-N022BI1E51-N023B) 67 98 103 Hx Rm (1G31-N016E) 150 212.5 104 Hx Rm DIFF (1G31-N022A/1G31-N023A) 67 98 105 Phase Sep Rm (1G31-N016A) 150 212.5 106 Phase Sep Rm DIFF(1G31-N022E/1G31-N023E) 67 98 SOUTHEAST DIAGONAL AREA 107 RHR/CS A(1E11-N009A) 150 212.5 108 RHR/CS A DIFF (1E11-N030A/1E11-N029A) 40 98 HPCl ROOM AREA 109 Pump Rm (1E41-N024) 167.5 245 110 EmerArea Clr(1E41-N030A) 167.5 245 RCIC ROOM AREA 112 Pump Rm (1E51-N011) 167.5 310 113 EmerArea CIr (1E51-N023A) 167.5 310 TORUS ROOM AREA 115 West Wall (1E51-N025A) 167.5 212.5 116 Southeast Wall (1E51-NO25C) 167.5 212.5 117 VENT AIR DIFF (1E51-N026A11E51-N027A) 42 102 118 VENT AIR DIFF (1E51-N026C/1E51-N027C) 42 102 MAIN STEAM LINE TUNNEL AREA 119 Main Stm Tnl (1B21-N014) 192.5 300 120 1B21-N016A/N016B DIFF 60 150 HPCI PIPE PENETRATION ROOM 121 1E41-N046A 150 212.5 I/RDG RDG RDG 1 2 3 I________Iec 4B-2-0-MGR-0009 Rev 5.0 V18 Page 5 of 10 PAGE 29 OF 30 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMET ITE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL 34AB-T22-003-1 5.14 ATTACHMENT 10 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT PARAMETERS 1 OF 1 I max 14" aow8rTelw.

Ir Irt' 3TabowSTe~ev.

t#' aovSe lteev.DIAGONALAREA 150 212.5 I.IV ROOMAIEA wI' h svIo"fl vi" IT 71e, CO4hNMEN REFA RADIATIONIMONITORS I [g~11.SS 1211UV~jteVae IEREL FLO(F AREA 1Reathe.J iee (1D21-KG00A) 50 1000 2 a u(IO141-01 B) 50 10(00 3 P.uuI o(1O21-K60lD) 50 1000 4 Dr~weIl 50 1000 5 SpeltFtmlPool&New~uelStcrage(1D21.K501M 50 1000 5RB20Wor~ru(1D21K0 X) 50 7 SpentFuel PoC DeuinvEquip{1O21.01C) 150 I1Q000 eFu.PocDsrmin, Pmn(1D21.K17) 50 10 ___9 R81irWokArea(1D214K601K) 50 1 000 10 RxbSarjiRzdkue (ID214K601L) 50 1 000)11 50 IOQ00 12 NothCRVHCU(1021-IQD1P) 50 I1000 14 R8130N.E~odinku(1D21.K601G) 50 I1000 15 50 ]1000 __ELEVATION SOUTH AREA 16 50 1000 17 SoutthCAOHCJ(1D2FH(0tN) 50 1000 _18 RCCEEupSWDmgna(1O21.KO1V) 50 I1000 NORfN"TI~LAOA AREA 19 CR)PumpiWOIagvnI(1D21.(801W) 50 I1000 NOfES G4LAREA 20 CS&RJIRN~.Edg(1D21-KIE01Y) 50 1000 SOUT~fJST ENA-(NAL ARE --_ -21 CS&Rk-IlS,,EDigoza{IDT2.K6O1R) 50 1 (000!J7 ELEVATION AREA ET 22 HFOTuwtmieAlui1D214t01T) 150 I10(00 1OP114S-~1933~

I l=l 1 I 34AB-T22-O03-1 OPS-1 933 MGR-0009 Rev 5.0 V1 8 Page 6 of 10 PAGE 9 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOUMNTTILE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-2 4.2 ATTACHMENT 2 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 1 (2G31-R604)_________

MAX NORMAL MAX SAFE SECONDARY CONTAINMENT TEMP ON 2H11-P614, OPERATING OPERATING 2G31-R604 VALUE VALUE°F °F 158' ELEVATION AREA (RWCU)101. B pump room (2G31-N016B) 150 215 102. B pump room DIFF (2G31-N023B/2G31-N022B) 67 99 103. Hx Room (2G31-N016D) 150 215 104. Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99 185' ELEVATION AREA (RWCU)105. Valve Nest (2G31-N016F) 150 215 106. Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 99 SOUTHEAST DIAGONAL AREA 107. RHR/CS B (2E11-N009B) 150 190 108. RHR/CS B DIFF (2E11-N030B/2E11-N029B) 40 74 HPCI ROOM AREA 109. Emer area clr (2E41-N030B) 167.5 245 110. HPCl vent air DIFF (2E41-N029B/2E41-N028B)

NA NA (not used)______

____RClC ROOM AREA 111. Emer Area CIr (2E51-N023B) 167.5 310 112. RCIC vent air DIFF (2E51-N022B/2E51-N021B)

NA NA (not used)______

____TORUS ROOM AREA 113. Northwest Wall (2E51-N025B) 167.5 212.5 114. Southeast Wall (2E51-N025D) 167.5 212.5 115. Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98 116. Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98 HPCI PIPE PENETRATION ROOM 117. 2E41-N046B 167.5 212.5 Vi18 Page 7 of 10 PAGE 10 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-2 4.2 ATTACHMENT 3 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (2G31 -R608) 1 OF 1 MAX NORMAL MAX SAFE SECONDARY CONTAINMENT TEMP ON 2H1 1-P614, OPERATING OPERATING 2G31-R608 VALUE VALUE°F °F 158' ELEVATION AREA (RWCU)101. A Pump Room (2G31-N016A) 150 215 102. A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 99 103. Hx Room (2G31-N016C) 150 215 104. Hx Room DIFF (2G31-N023C/2G31-N022C) 67 99 105. Phase Sep Rm (2G31-N016E) 150 215 106. Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 99 NORTHEAST DIAGONAL AREA 107. RHR/CS A (2E1 1-N009A) 150 215 108. RHR/CS A DIFF (2E11-N030AN2E11-N029A) 40 74 HPCI ROOM AREA 109. Pump Rm (2E41-N024) 167.5 245 110. Emer Area CIr (2E41-N03OA) 167.5 245 111. HPCI Vent Air DIFF (2E41-N029A/2E41-N028A)

NA NA (not used)__________

RCIC ROOM AREA 112. Pump Rm (2E51-N011) 167.5 310 113. Emer Area CIr (2E51-N023A) 167.5 310 114. RCIC Vent Air DIFF (2E51-N022A12E51-N021A)

NA NA (not used)TORUS ROOM AREA 115. West Wall (2E51-N025A) 167.5 212.5 116. Northeast Wall (2E51-N025C) 167.5 212.5 117. Torus Vent Air DIFF (2E51-N027A/2E51-N026A) 42 98 118. Torus Vent Air DIFF (2E51-N027C/2E51-N026C) 42 98 MAIN STEAM LINE TUNNEL AREA 119. Main Steam Tunnel (2B21-N014) 192.5 310 120. Main Stm Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150 HPCI PIPE PENETRATION ROOM 121. 2E41 -N046A 167.5 212.5 V18 Page 8 of 10 PAGE 30 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMET ITE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2 ATTACHMENT

_9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2 SECONDARY CONTAINMENT TEMPMMA on 2H11-P614, 2G31-R604 NORMALj SAFE 158' ELEVATION AREA (RWCU)101 B pump room (2G31-N016B) 150 215 102 B pump room DIFF (2G31-N023B/2G31-N022B) 67 99 103 Hx Room (2G31-NO16D) 150 215 104 Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99 185' ELEVATION AREA (RWCU)105 Valve Nest (2G31-N016F) 150 215 106 Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 9 SOUTHEAST DIAGONAL AREA 107 RHR/CS B (2E11-N009B) 150 J190 108 RHR/CS B DIFF (2E1 1-N030B/2G31-N029B) 40 J 74 HPCI ROOM AREA 109 Emer Area CIr (2E41-N030B)

I67.5 245 RCIC ROOM AREA 111 Emer Area CIr (2E51-N023B)

16. 1 TORUS ROOM AREA 113 Northwest Wall (2E51-N025B) 167.5 212.5 114 Southeast Wall (2E51-N025D) 167.5 212.5 115 Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98 116 Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98 HPCI PIPE PENETRATION ROOM 117 2E41-N046B Ii7.5I 212.5 Values displayed in the NORM column (green) represent the values at 100% rated thermal power, summertime conditions.

POSTED AT 2H1 1-P614 SOUTHERN NUCLEAR PLANT E.I. HATCH Vi18 Page 9 of 10 PAGE 31 OF 37 DOCMET ITE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAINMENT CONTROL 34AB-T22-003-2 4.2 ATTACHMENT 9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2 SECONDARY CONTAINMENT TEMP MAX MAX on 2H11-P614, 2G31-R608 NORMAL[ SAFE 158' ELEVATION AREA (RWCU)101 A Pump Room (2G31-N016A) 150 21 102 A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 9 103 Hx Room (2G31-N016C) 150 21 104 Hx Room DIFF (2G31-N023C/2G31-N022C) 67 9 105 Phase Sep Rm (2G31-N016E) 150 21 106 Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 9 NORTHEAST DIAGONAL AREA 107 RHR/CS A (2E1 1-N009A) 150 21 108 RHR/CS A DIFF (2E11-N030AI2E11-N029A) 40 174 HPCl ROOM AREA 109 Pump Rm (2E41-N024) 167.5 245 110 Emer Area Clr(2E41-N030A) 167.5/ 245 RClC ROOM AREA 112_Pump Rm_(2E51-N011) 167.5 _310 113 Emer Area Clr (2E51-N023A) 167.5 310 TORUS ROOM AREA 115 West Wall (2E51-N025A) 167.5 212.5 116 Northeast Wall (2E51-N025C) 167.5 212.5 117 Torus vent air DIFF (2E51-N027A12E51-N026A) 42 98 118 Torus vent air DIFF (2E51-N027C/2E51-N026C) 42 98 MAIN STEAM LINE TUNNEL AREA 119 Main Steam Tunnel (2B21-N014) 192.5 310 120 Main Steam Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150 RDG RDG 1 RDG 1 2 3-B_HPCl PIPE PENETRATION ROOM I 121 2E41,N046A

[167.5 212.5_Values displayed in the NORM column (green) represent the values at 100% rated thermal power, summertime conditions.

POSTED AT 2H1 1-P614 V1 8 Page 1 0 of 10 PAGE 35 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMEN TILE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2 ATTACHMENT 1"1 ATTACHMENT PAGE: TITLE: SECONDARY CONTAI NMENT PARAMETERS 1 OF 1 Table 4 o'9tA~hG~iWAfli I I C0NbleN 5 A 101 102 AREA WATER LEVELS Max Nanul MaxSafe.___ 4" r/5T'sia 33 isv .1.AREA 4"iow ST ealeion!$"o8T 1ev'.4icvelTelwian 27.bovel7'elw.

diov.STal.vglwi t#' above $'t' 4" isve 8'uleiion 14" isy rr sh, 4 aov 57' ekydon tt" above 37' .ev.Table 6 ARIA MOR10.3 yaw aw S UUHd113 l 51-N058) I167.5 212.5 114 Sou WlbeI (2E514NU50) l167.5 212.5 116 ToqusM VtOIFF 42 9 01 A Pw~own%2;G31.#408A o mpRoooN2G314 t3Phu Sep Rm(2m1.N01E)

Va 150 67'so 57 150 Ri Va 215 99 215 98 215 1 Reac had (2D21-K601A) 50 1Q000 3 SfouIlo&NswFu l~g.(2f21.KBO1M) 50 1000 4 ahFboor(2D214(SI11K) 5o 10o0 G Reeor Vesse!RFloor (2Q21.K811 L) 50 1Q000 63 (2D214,SO1T) 50 10]00 7 HV o¢W 50 100 8 Spn u olPsaea 50 1000 9 RB 18 qelegIoor(2O21..KO0R) 50 1000 10 R81W Samispuue t.lme(221.(8O1S) 50 1Q000 I'I R818 cou~rol pa-.(2O21-K601U) 15O t000__13 S reaIW (2D21.(501D) 50 1000__15Dean um eupmntronara 50 1000__

`1000 1307 ELEVATION ARE.A (NSRUThWS N(R11PMB(2T2IMOIF)

L AO RtOA 217 50 .1000 22 RC1S.W4~odgAii(2D21,,K601X) 50 .1000 23 cs&rRls~dagoi(2V214WO1Y) 150 1000O 115 16+7.5 21 215 42 198l34AB-.T22-003-2 OPS-1932 OPS-1 932 V19 Page 1 of 4 PAGE 2 OF 3 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO: ARP'S FOR CONTROL PANEL 2H1 1-P657, 34AR-657-901-2 I 23.1 ALARM PANEL 1 UNIT 2 2H11-P657

-1 (LEFT)657-001 657-002 657-00.3 557-004 57-005 657-006 657-007 657-008 657-009 657-019 657-020 657-021 57-02 657-023 657-024 657-025 657-026 657-027 657-037 657 -03 6 57-03;;57-040 6 7-041 657-042 657-043 657-044 657-045 657-055 657-05S G57 057 657-058 -5705 657-060 657-061 657-062 657-063 657-07 657-074 657-075 657-0Th 657-77 657-07 657-079 657-080 657-081 657-091 57 0 2 657-093 557-094 657-095 657 096 65-097 657-098 657-099 2H11-P657

-1 (RIGHT)657-010 657-011 G57-012 657-013 657-014 657-015 657-016 657-017 657-018 657-028 ss57-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036 657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054 657-064 65 7-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072 657-082 657-0B3 65-084 657-085 657-086 657-087 657-088 657-089 657-090 657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108 Level Of Use ARPs CONTINUOUS ALL REFERENCE None INFO None Vi19 Page 2 of 4 1.0 IDENTIFICATION:

ALARM PANEL 657__ _______SEISMIC* INSTRUMENTATION TRIGGERED DEVICE: SETPOINT: 2L51-N022 0.08 g horizontal, 0.54 g vertical 2L51 -N024 0.18 g horizontal, 0.063 vertical 2.0 CONDITION:

3.0 CLASSIFICATION

[ EQUIPMENT STATUS Motion has been detected in Unit 2 Reactor Building on4.LOAIN elevation 87' or 185' 4 H0 LOCATION 5.0 OPERATOR ACTIONS: 5.1 At Panel 1 Hi11-P701, check for further indications of a seismic event by 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). LII 5.2 Refer to Seismic Instrumentation Earthquake Response Manual, SX-18271, for guidance in analyzing seismic data. LI 5.3 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon.

LI 5.4 Enter NMP-EP-1 10, Emergency Classification Determination and Initial Action. LI 5.5 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. LI 6.0 CAUSES: Seismic event

7.0 REFERENCES

8.0 TECH. SPECS./TRMIODCMIFHA:

7.1 H-16319, Seismic Measurement Equip Control TRM T3.3.6 Seismic Monitoring Panel & Instrumentation.

Instrumentation 7.2 H-17978, Seismic Measurement Equip Sys L51 Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651 Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-048-2 VER 4.1 MGR-0048 Ver. 5.0 Vi19 Page 3 of 4 UNIT 1 IH11-P657

-1 (RIGHT)657-010 657-011 657-012 657-013 657-014 657-015 657-016 657-017 657-018 657-028 657-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036 657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054 657-064 657-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072 657-082 657-083 657-084 657-085 657-086 657-087 657-088 657-089 657-090 657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108 RECORDS There are no records generated by the procedure COMMITMENTS NONE MGR-0001 Ver. 4 V19 Page 4 of 4 1.0 IDENTIFICATION:

ALARM PANEL 657________

SEISMIC PEAK SHCKRECORDERJ DEVICE: SETPOINT: 1 L51-Vbc-R620 Not available 5.0 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). El 5.2 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 El 5.3 Refer to SX-18271, Seismic Instrumentation Earthquake Response Manual, for guidance in analyzing seismic data. El 5.4 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon.

El 5.5 Enter 73EI-EIP-001-0, Emergency Classifications and Initial Actions. El 5.6 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. El 6.0 CAUSES: 6.1 Seismic event 6.2 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 Monitors Panel and Instrumentation.

7.2 H-17978, Seismic Measurement Equip Sys L51 Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651 Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-066-1I Ver. 3.0 MGR-0048 Ver. 5 AG-MGR-75-1101 V20 Page 1 of 20 SOUTERN UCLAR DCUMNT TPE:PAGE PLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 118 DOCMEN TILE:DOCUMENT NUMBER: VERSION NO: FIRE PROCEDURE 34AB-X43-001-1 13.1 EXPIATIN APROVLS:EFFECTIVE DATE: DEPARTMENT MGR Daniel A. Komm DATE 8-1 1-14 DATE: N/A SSM /PM N/A DATE N/A 9-11-14 1.0 CONDITIONS A fire exists at Plant E. I. Hatch. This procedure provides information AND actions necessary to mitigate the consequences of fires AND to maintain an operable shutdown train following fire damage to specific areas.TABLE OF CONTENTS Section Paae 2.0 AUTOMATIC ACTIONS..........................................................................

3 3.0 IMMEDIATE OPERATOR ACTIONS ............................................................

3 4.0 SUBSEQUENT OPERATOR ACTIONS.........................................................

4 5.0 CONTROL BUILDING............................................................................

7 5.4 112 FT. ELEVATION

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

7 5.5 OIL STORAGE TANK ROOM ...............................................................

7 5.6 STATION BATTERY ROOMS ...............................................................

8 5.7 RPS BATTERY ROOMS.....................................................................

8 5.8 130 FT ELEV. PASSAGEWAYS, HVAC ROOM, HP AREA, RADWASTE LAB .........

8 5.9 RPS MG SET ROOM ........................................................................

8 5.10 OIL CONDITIONER ROOM .................................................................

9 5.11 DC SWITCHGEAR ROOMS.................................................................

9 5.12 600V SWITCHGEAR ROOM iC ............................................................

9 5.13 600V SWITCHGEAR ROOM 1D...........................................................

10 5.14 TRANSFORMER lCD ROOM .............................................................

10 5.15 MAIN CONTROL ROOM, CABLE SPREADING ROOM OR COMPUTER ROOM ....11 5.16 CONTROL ROOM ROOF ..................................................................

13 5.4 112 FT. ELEVATION........................................................................

14 6.0 DIESEL GENERATOR BUILDING .............................................................

15 6.2 DG BATTERY ROOMS.....................................................................

15 6.3 DG DAY TANK ROOMS....................................................................

16 6.4 DG ENGINE ROOMS ......................................................................

17 6.5 DG 1A SWGR ROOM 1E (1R22-S005)....................................................

18 6.6 DG lB SWGR ROOM iF (1R22-S006)....................................................

19 6.7 DG 1C SWGR ROOM 1G (1R22-S007)...................................................

20 7.0 YARD .............................................................................................

21 7.2 COOLING TOWER .........................................................................

22 7.3 INTAKE STRUCTURE......................................................................

22 7.4 CONDENSATE STORAGE TANK AREA .................................................

22 7.5 NITROGEN STORAGE TANK AREA......................................................

23 SOUTHERN NUCLEAR PLANT E. I. HATCH I V20 Page 2 of 20 PAGE 2 OF 118 DOCMEN TTLE IDOCUMENT NUMBER: IVERS ION NO: FI RE PROCEDURE 34AB-X43-001-.1 j 13.1 7.6 MAIN OR UNIT AUXILIARY TRANSFORMER............................................

23 7.7 STARTUP AUXILIARY TRANSFORMER.................................................

23 7.8 AUXILIARY BOILER........................................................................

23 7.9 COOLING TOWER SWITCHGEAR HOUSE..............................................

23 7.10 WASTE GAS TREATMENT BUILDING...................................................

23 7.11 FIRE PUMP HOUSE........................................................................

23 7.12 CONDENSATE DEMINERALIZER BUILDING (MUD HOUSE)..........................

23 7.13 CHLORINE BUILDING......................................................................

24 7.14 SECURITY CAS BUILDING................................................................

24 7.15 CIRCULATING WATER PUMP PIT .......................................................

24 7.16 RECOMBINER BUILDING .................................................................

24 7.17 TSC24 7.18 HIGH VOLTAGE SWITCHYARD

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

24 7.19 DISCHARGE STRUCTURE................................................................

24 7.20 MAIN STACK................................................................................

24 7.21 DEEPWELL PUMP HOUSE................................................................

24 7.22 HYDROGEN/OXYGEN BULK STORAGE FACILITY.....................................

24 7.23 HYDROGEN/OXYGEN SUPPLY INTERMEDIATE VALVE STATION..................

25 7.24 HYDROGEN/OXYGEN TURBINE BLDG ISOLATION VALVE STATION...............

25 7.25 HP/CHEMISTRY FILTER TRAIN (NORTH SIDE OF SECURITY CAS BLDG).........

26 7.26 ISFSI / DRY STORAGE AREA (SOUTH OF PROTECTED AREA) .....................

26 8.0 UNIT 1 REACTOR BUILDING..................................................................

27 8.3.3 Torus Room, South Half...............................................................

27 8.3.4 RClC Room ............................................................................

28 8.3.5 Div I RHR and Core Spray Corner Room ............................................

28 8.4.3 Torus Room, North Half ...............................................................

29 8.4.4 CRD Room.............................................................................

30 8.4.5 Div II RHR and Core Spray Corner Room............................................

31 8.4.6 HPCl Room.............................................................................

31 8.4.7 130 Ft Elevation, North Half...........................................................

32 8.4.8 158 Ft Elevation, North Half...........................................................

33 8.4.9 164 Ft HVAC and SBGT Room .......................................................

34 8.4.10 Fuel Pool Cooling and Heat Exchanger Room.......................................

37 8.4.11 RWCU Equipment Room..............................................................

37 8.4.12 203 Ft...................................................................................

38 8.5 REClRCULATION PUMP / ASD AREA MG SET ROOM ................................

38 8.6 DRYWELL...................................................................................

39 9.0 TURBINE BUILDING ...........................................................................

40 9.2 TURBINE BUILDING OR WEST CABLEWAY............................................

40 9.3 EAST CABLEWAY..........................................................................

41 9.4 EAST CABLEWAY FOYER ................................................................

41 10.0 RADWASTE BUILDING ........................................................................

42 11.0 RECORDS.......................................................................................

43 12.0COMMITMENTS

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

43 V20 Page 3 of 20 SNC PANT .I.HATC I I Pg 85 of 118 DOCMEN TTLE IDOCUMENT NUMBER:I Version No: FI RE PROCEDURE 34AB-X43-001-1 13.1 ATTACHMENT 2_ Attachment Page TITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 1 OF 5*The Safe Shutdown Paths listed below indicate the Safe Shutdown Train that has been protected for a fire in the associated area. The Safe Shutdown path (1 OR 2) least impacted by the fire in each area was identified AN..._D protected.

It is assumed that only one path is available for shutdown for the purpose of engineering analysis.

This does NOT prevent operator use of systems outside of the protected path, IF they continue to function as required.

For fire areas where protection of one path cannot be achieved, such as the Main Control Room, Cable Spreading Room, AND Computer Room, 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 operator action, those actions are contained in this procedure.

The components that are protected WITHIN each Safe Shutdown Path, as determined below, are given in Attachment 3 (Path 1), Attachment 4 (Path 2), AN Attachment 5 (Path 3 OR Remote Shutdown).

These component lists are to be considered the minimum equipment that will survive in a given fire area. Other equipment, although NO_._I specifically protected OR analyzed, may survive the fire. Circuit faults to unanalyzed equipment have NOT been evaluated.

V20 Page 4 of 20 SNC LAN E.I. HTCHI IPg 86 of 118 DOCMEN TTLE IDOCUMENT NUMBER:I Version No: FIRE PROCEDUREI 34AB-X43-001-1 13.1 ATTACHMENT 2_ Attachment Page TITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -UI 2 OF 5 PREFIRE PLAN DWG #CONTROL BUILDING 112 FT. ELEV PASSAGEWAYS OR SERVICE AIR COMPRESSOR ROOM OIL RESERVOIR ROOM FREIGHT ELEVATOR OR STAIRWAY AC INVERTER ROOM STATION BATTERY ROOM 1A STATION BATTERY ROOM 1 B RPS BATTERY ROOM 1A RPS BATTERY ROOM lB WATER ANALYSIS ROOM OR HOT INSTRUMENT SHOP UNIT 1 130 FT ELEV PASSAGEWAYS HVAC ROOM -130 FT ELEV RPS MG ROOM VERTICAL CABLE CHASE ANNUNCIATOR ROOM OIL CONDITIONER ROOM DC SWGR ROOM 1A DC SWGR ROOM lB HEALTH PHYSICS AREA OR RADWASTE LAB 600V SWGR ROOM 1C 600V SWGR ROOM 1D TRANSFORMERS ROOM lCD CO 2 STORAGE TANK AREA MAIN CONTROL ROOM CABLE SPREADING ROOM COMPUTER ROOM A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43 965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 SHT #5A, B 10A,B 6A, B 13A,B 11A,B 12A,B 15A, B 1 4A, B 8A, B 24A,B 25A, B 26A,B 26A,B 27A,B 33A, B 30A, B 32A,B 23A, B 28A,B 29A,B 31A,B 46A, B 48A,B 44A,B 45A, B PROTECTED SAFE SHUTDOWN PATH 2 1 and 2 2 1 2 1 1 and 2 1 and 2 1 2 2 1 2 2 2 2 1 2 2 1 2 2 REMOTE SHUTDOWN SYSTEMS REMOTE SHUTDOWN SYSTEMS REMOTE SHUTDOWN SYSTEMS 2 CONTROL ROOM ROOFA4365A, A-43965 50A, B V20 Page 5 of 20 SNC LANTE. I HATH IPg 87 of 118 DOCMEN TTLE IDOCUMENT NUMBER: Version No: FIRE PROCEDURE1 34AB-X43-001-1 13.1 ATTACHMENT 2 Attachment Page TITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 3 OF 5 DIESEL GENERATOR BUILDING DG BUILDING HALLWAY DG 1A BATTERY ROOM DG 1 B BATTERY ROOM DG lC BATTERY ROOM DG 1A DAY TANK ROOM DG 1 B DAY TANK ROOM DG 1 C DAY TANK ROOM DG 1A ENGINE ROOM DG lB ENGINE ROOM DG 1C ENGINE ROOM DG 1A SWGR ROOM DG 1B SWGR ROOM LDG lC SWGR ROOM PREFIRE PLAN DWG #A-43966 A-43966 A-43966 A-43 966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 SHT #5A, B 15A,B 11A,B 7A,B 1 4A, B 10A, B 6A, B 16A, B 12A, B 8A,B 1 7A, B 13A, B 9A, B 1 and 2 2 1 and 2 1 2 1 and 2 1 2 2 1 2 2 1 PROTECTED SAFE SHUTDOWN PATH YARD COOLING TOWERS INTAKE STRUCTURE PLANT SERVICE WATER VALVE PIT 2A PLANT SERVICE WATER VALVE PIT 2B CONDENSATE STORAGE TANK AREA NITROGEN STORAGE TANK AREA TRANSFORMERS AUXILIARY BOILER CIRC WATER PUMP PIT FIRE PROTECTION PUMP HOUSE, WEST AREA A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 74A, B thru 76C,D 27A, B 50A, B 51A,B 43A,B 41 A, B 56A, B 61A,B 52A,B 46A,B 1 and 2 1 and 2 2 1 1 1 1 and 2 NA 2 1 and 2 V20 Page 6 of 20 SNC LANTE. I HATH IPg 88 of 118 DOUMNTTILE IDOCUMENT NUMBER: Version No: FIRE PROCEDUREI 34AB-X43-00 1-1 13.1 ATTACHMENT 2_ Attachment Page TITLE: PRE PLANS AND SAFE SHUTDOWN PATHS -U1 4 OF 5 REACTOR BUILDING PREFIRE PLAN DWG #PROTECTED SAFE SHUTDOWN PATH SHT #51A,B DIV I RHR AND CORE SPRAY SE CORNER ROOM DIV II RHR AND CORE SPRAY NE CORNER ROOM CRD CORNER ROOM RCIC ROOM HPCI ROOM TORUS ROOM -SOUTH HALF TORUS ROOM -NORTH HALF 130 FT ELEV -SOUTH 130 FT ELEV -NORTH REClRC ASD ROOM 1A RECIRC ASD ROOM lB RWCU PUMP A ROOM RWCU PUMP B ROOM 158 ELEV -WORKING FLOOR DECANT PUMP ROOM 164 FT ELEV HVAC ROOM FUEL POOL COOLING AREA SR-1205R RWCU EQUIPMENT AND SAMPLING ROOMS SUPPLY FAN ROOM 185 FT WORKING FLOOR TURBINE BUILDING EXHAUST FILTER ROOM SBGT ROOM 203 FT WORKING FLOOR 203 FT REFUELING AIR SUPPLY ROOM 228 FT REFUELING FLOOR DRYWELL AND TORUS A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 2 53A,B 1 54A, B 1 52A,B 2 55A,B 1 56A, B 2 57A,B 1 58A,B 2 59A,B 1 63A,B 2 64A,B 1 and 2 62A,B 1 62A,B 1 61A,B 1 61A,B 1 65A,B 1 67A,B 1 69A,B 1 69A,B 1 68A,B; 67A,B 1 71A,B 1 66A,B 1 73A,B 1 73A,B 1 74A,B 1 and 2 56A,B & 1 and 2 57A,B (Torus Room Only)PROTECTED SAFE SHUTDOWN SHT # PATH PREFIRE PLAN DWG #TURBINE BUILDING EAST CABLEWAY TURBINE BUILDING WEST CABLEWAY TURBINE DECK STAIRWAYS EAST CABLEWAY FOYER A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 34A,B N/A 81A,B 87A,B, 88A, B N/A 34A, B 1 2 2 2 2 2 V20 Page 7 of 20 SNC LAN E.I. HTCHI IPg 90 of 118 DOCMEN TTLE IDOCUMENT NUMBER:I Version No: FIRE PROCEDURE 34AB-X43-001-1 13.1 ATTACHMENT 3_ Attachment Page TITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 1 1 OF 8 1.0 PATHWAY 1 TO SHUTDOWN Systems Required 1.1.1 RHR, Pump A; RHR Service Water Pump A.1.1.2 RClC 1.1.3 SRVs, Gand H 1.1.4 Plant Service Water, Pump A 1.1.5 RHR and RClC Emergency Room Ventilation System, A Coolers 1.1.6 RPV Instrumentation 1.1.7 Containment Instrumentation 1.1.8 Drywell Air Supply 1.1.9 Diesel Generator and Associated Electrical Equipment 1.1.10 MSIVs 1.1.11 Diesel Building Ventilation 1.1.12 Intake Structure Ventilation V20 Page 8 of 20 SNC LAN E.I. HTCHI lPg 98 of 118 DOCMEN TTLE IDOCUMENT NUMBER:I Version No: FI RE PROCEDURE 34AB-X43-001

-1 13.1 ATTACHMENT 4 Attachment Page TITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 2 1 OF 8 2.0 PATHWAY 2 TO SHUTDOWN 2.1 Systems Required 2.2.1 RHR System, Pump B; RHR Service Water Pump B.2.2.2 RHR and HPCI Room Coolers, B Coolers 2.2.3 Plant Service Water, Pump B 2.2.4 RPV Instrumentation 2.2.5 Containment Instrumentation 2.2.6 Drywell Air 2.2.7 Diesel Generator and Associated Electrical Equipment 2.2.8 HPCI 2.2.9 Core Spray (for Fire Area 1203 only)2.2.10 SRVs, A and C.2.2.11 MSIVs 2.2.12 Diesel Building Ventilation 2.2.13 Intake Structure Ventilation V20 Page 9 of 20 SNC LANTE. I HATH IPg 106 of 118 DOCMEN TTLE IDOCUMENT NUMBER: Version No: FIRE PROCEDURE 34AB-X43-001-1 13.1 ATTACHMENT 5 Attachment Page TITLE: SAFE SHUTDOWN COMPONENTS LIST -PATH 3 I OF 8 3.0 PATHWAY 3 TO SHUTDOWN 3.1 Systems Required 3.2.1. RHR System, Pump B; RHR Service Water Pump B 3.2.2. RHR and RCIC Room Coolers 3.2.3. Plant Service Water, Pumps A and B.3.2.4. RPV Instrumentation 3.2.5. Containment Instrumentation 3.2.6. Drywell Air 3.2.7. Diesel Generator and Associated Electrical Equipment 3.2.8. RCIC 3.2.9. SRVs, C and G.3.2.10. MSIVs 3.2.11. Diesel Building Ventilation 3.2.12. Intake Structure Ventilation V20 Page 10 of 20 SOUTERNNUCEAR I DOUMET TPE:PAGE PLANT E. I. HATCH ABNORMAL OPERATING PROCEDURE 1 OF 114 DOCUENTTITL:

IDOCUMENT NUMBER: VERSION NO: FIRE PROCEDURE 34AB-X43-00 1-2 15.0 EXPIATIN APROVLS:EFFECTIVE DATE: DEPARTMENT MGR Daniel A. Komm DATE 3-18-15 DATE: N/A SS M/PM N/A DATE N/A 3-18-2015 TABLE OF CONTENTS Section Page 1.0 CONDITIONS.....................................................................................

3 2.0 AUTOMATIC ACTIONS..........................................................................

3 3.0 IMMEDIATE OPERATOR ACTIONS ............................................................

3 4.0 SUBSEQUENT OPERATOR ACTIONS.........................................................

4 5.0 CONTROL BUILDING............................................................................

7 5.1 Control Building Ventilation Fans............................................................

7 5.2 Ventilation Restoration.......................................................................

7 5.3 Control Building Specific Area Actions......................................................

8 5.4 Oil Storage Tank Room ......................................................................

8 5.5 Station Battery Rooms (FA 2005) ...........................................................

8 5.6 RPS Battery Rooms..........................................................................

8 5.7 130 ft elev. Passageways, HVAC Room and Lab ..........................................

8 5.8 Annunciator Room ...........................................................................

9 5.9 Oil Conditioner Room (FA 2023) ............................................................

9 5.10 RPS MG Set Room and Vertical Cableway.................................................

9 5.11 DC Switchgear Rooms.......................................................................

9 5.12 Switchgear Access Hallway & 600V Switchgear Room 2C...............................

10 5.13 600V Switchgear Room 2D.................................................................

11 5.14 Transformer Room 2CD ....................................................................

12 5.15 Main Control Room, Cable Spreading Room or Computer Room .......................

13 5.16 Control Building 112 ft Elevation Working Floor, Corridor, and Annunciator Logic Cabinet (FA 0001)....................................................................................

14 5.17 Water Analysis Room (FA 2006)...........................................................

14 6.0 DIESEL GENERATOR BUILDING.............................................................

15 6.1 Diesel generator Building Specific Area Index ............................................

15 6.2 DG Battery Rooms..........................................................................

15 6.3 DG Day Tank Rooms .......................................................................

16 6.4 DG Engine Rooms..........................................................................

18 6.5 DG 2A Swgr Room 2E (2R22-S005)

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

19 6.6 DG 1B Swgr Room 2F (2R22-S006)

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

20 6.7 DG 2C Swgr Room 2G (2R22-S007)

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

21 7.0 YARD ............................................................................................

22 7.1 Plant Yard Specific Area Index.............................................................

22 7.2 Intake Structure

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

22 7.3 Nitrogen Storage Tank AREA..............................................................

23 V20 Page 11 of 20 PAGE 2 OF 114 SOUTHERN NUCLEAR PLANT E. I. HATCH DOCMEN TILE:DOCUMENT NUMBER: VERSION NO: FIRE PROCEDURE 34AB-X43-001

-2 15.0 7.4 Main or Unit Auxiliary Transformer.........................................................

23 7.5 Startup Auxiliary Transformer

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

23 7.6 Auxiliary Boiler ..............................................................................

23 7.7 Waste Gas Treatment Building....................,.........................................

23 7.8 High Voltage Switchyard

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

23 7.9 Circulating Water Pump Pit ................................................................

23 8.0 REACTOR BUILDING ..........................................................................

24 8.1 Reactor Building Ventilation................................................................

24 8.2 Reactor Building Specific Area Index......................................................

24 8.3 North Half of Reactor Building Below 185 ft ...............................................

25 8.4 ASD Rooms .................................................................................

27 8.5 South Half of Reactor Building, and All of the 185 ft and 203 ft Elevations

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

28 8.6 Drywell.......................................................................................

38 9.0 TURBINE BUILDING ...........................................................................

39 9.1 Turbine Building Specific Area Index ......................................................

39 9.2 Turbine Building.............................................................................

39 9.3 Turbine Building Unit 2 East Cableway (2104)............................................

40 9.4 Turbine Building East Cableway Foyer ....................................................

40 9.5 Turbine Building Unit 1 East Cableway....................................................

41 10.0 RADWASTE BUILDING .......................................................................

42 10.1 Ventilation Charcoal Filter trains ...........................................................

42 11.0 RECORDS .....................................................................................

43 12.0 COMMITMENTS...............................................................................

43 Attachments 1 SAFE SHUTDOWN ACTIONS .................................................................

44 2 PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 ................................

85 3 SAFE SHUTDOWN PATHS FOR UNIT 2 FOR UNIT 1 FIRES ..............................

89 4 SAFE SHUTDOWN COMPONENT LIST PATH 1I............................................

90 5 SAFE SHUTDOWN COMPONENT LIST PATH 2 ............................................

96 6 SAFE SHUTDOWN COMPONENT LIST PATH 3 ...........................................

103 7 LINKS NORMALLY OPEN TO SUPPORT APPENDIX R ...................................

110 8 REFERENCE DRAWINGS LIST..............................................................

111 9 PLACARDS FOR 2H11-P601.................................................................

113 10 KEY MILESTONES FORA FIRE OR FIRE DRILL ..........................................

114 V20 Page 12 of 20 SOUTERN UCLER IPAGE PLAN E. .HACHJ250OF 114 DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO: FIRE PROCEDURE 34AB-X43-001

-2 15.0 8.3 NORTH HALF OF REACTOR BUILDING BELOW 185 FT. ELEVATION 8.3.1 IF a reactor SCRAM has occurred, perform safe shutdown actions listed in Attachment 1, Step 8.3. LII 8.3.2 This fire area consists of the following fire zones, perform the steps applicable to the area: STEP ZONE PAGE 8.3.3 North Half of Torus Room ............................................................

25 8.3.4 RCIC Corner Room ...................................................................

25 8.3.5 Div I RHR and Core Spray Corner Room............................................

26 8.3.6 130 Ft Elevation, North Half..........................................................

26 Reactor 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 Room 8.3.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. Eli 8.3.4 RClC Corner Room 8.3.4.1 Stop RClC Pump Rm Coolers.* 2T41-B004A El* 2T41-B004B El 8.3.4.2 Close RClC Steam Supply Isol AND Steam Supply Line Isol Valves.* 2E51-F007 El* 2E51-F008 El V20 Page 13 of 20 PAGE 280OF 114 SOUTHERN NUCLEAR PLANT E. I. HATCH DOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO: FIRE PROCEDURE 34AB-X43-001-2 15.0 8.5 SOUTH HALF OF REACTOR BUILDING, AND ALL OF THE 185 FT AND 203 FT ELEVATIONS 8.5.1 IF a reactor SCRAM has occurred, perform safe shutdown actions listed in Attachment 1, Step 8.5. LI 8.5.2 This fire area consists of the following fire zones, perform the steps applicable to the fire zone: LI STEP ZONE PAGE 8.5.3 South Half of Torus Room...........

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

27 8.5.4 CRD Corner Room..................................................................

28 8.5.5 Div II RHR and Core Spray Corner Room (Southeast)

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

29 8.5.6 HPCI Room..........................................................................

29 8.5.7 130 Ft Elevation, South Half........................................................

30 8.5.8 158 Ft. Elevation South Half........................................................

30 8.5.9 164 Ft HVAC Room.................................................................

31 8.5.10 Fuel Pool Cooling And Heat Exchanger Room....................................

32 8.5.11 Fuel Pool and RWCU Precoat Equipment Area...................................

32 8.5.12 185 Ft Elevation Working Floor ....................................................

33 8.5.13 185 Ft HVAC Room.................................................................

34 8.5.14 Standby Gas Treatment Room.....................................................

34 8.5.15 203 Ft Working Floor................................................................

35 8.5.16 203 Ft HVAC Room.................................................................

35 8.5.3 South Half of Torus Room 8.5.3.1 De-energize affected equipment as requested by the Fire Brigade Leader. L[]

V20 Page 14 of 20 SNC LAN E.I. HTCHI I Pg 85 of 114 DOCMEN TTLE IDOCUMENT NUMBER:I Version No: FIRE PROCEDURE 34AB-X43-001-2 15.0 ATTACHMENT 2_ Attachment Page TITLE: 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 fire in the associated area. The Safe Shutdown Path (1 OR 2) least impacted by the fire in each area was identified AND analyzed.

It is assumed that only one path is available for shutdown for the purpose of engineering analysis.

This does NOT prevent Operator use of systems outside of the analyzed path IFE they continue to function as required.

For fire areas where protection of one path CANNOT be achieved, such as the Main Control Room, Cable Spreading Room AND Computer Room, Remote Shutdown Systems (Path 3) were identified AND~. analyzed.* Where circuit failures to analyzed path components can be compensated for by a manual operator action, those actions are contained in this procedure.

The components that are analyzed WITHIN each Safe Shutdown Path, as determined below, are given in Attachment 4 (Path 1), Attachment 5 (Path 2) AND Attachment 6 (Path 3 -Remote Shutdown).

These component lists are to be considered the minimum equipment that will survive in a given fire area. Other equipment, may survive the fire. Circuit faults to unanalyzed equipment have NOT been evaluated.

V20 Page 15 of 20 SNC LANTE. I HATH IPg 86 of 114 DOUMNTTILE IDOCUMENT NUMBER: Version No: FIRE PROCEDURE 34AB-X43-001

-2 15.0 ATTACHMENT 2 Attachment Page TITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 2 OF 4 ANALYZED PREFIRE PLAN SAFE SHUTDOWN CONTROL BUILDING DWG # SliT# PATH 112 Ft Elev Passageways, Hot Instrument Shop A-43965 5A, B 2 and Service Air Compressor Rooms Oil Storage Tank Room A-43965 1 6A, B 1 and 2 Freight Elevator or Stairway A-43965 6A, B 2 Station Battery Room 2A A-43965 1 7A, B 2 Station Battery Room 2B A-43965 1 8A, B 1 AC Inverter Room A-43965 20A, B 1 and 2 RPS Battery Room 2A A-43965 21A, B 1 and 2 RPS Battery Room 2B A-43965 22A, B 1 and 2 Water Analysis Room A-43965 1 9A, B 1 Unit 2 130 Ft Elev Switchgear Hallway A-43965 24A, B 2 Switchgear Hallway Enclosure A-43965 35A, B 2 All Other 130 Ft Elev Passageways A-43965 24A, B 2 HVAC Room -130 Ft Elev A-43965 25A, B 2 RPS MG Room A-43965 26A, B 1 Vertical Cable Chase A-43965 26A, B 2 Annunciator Room A-43965 36A, B 2 Oil Conditioner Room A-43965 42A, B 2 DC SWGR Room 2A A-43965 39A, B 2 DC SWGR Room 2B A-43965 41A, B 1 Rad Protection Area and Radwaste Lab A-43965 23A, B 2 600V SWGR Room 2C A-43965 37A, B 2I 600OV SWGR Room 2D A-43965 38A, B 1 2CD Transformer Room A-43965 40A, B 1 CO 2 Storage Tank Area A-43965 46A, B 2 LPCI Inverter Room A-43965 47A, B 2 Main Control Room A-43965 48A, B 3 Cable Spreading Room A-43965 44A, B 3 Computer Room A-43965 45A, B 3 Control Room Roof A-43965 50A, B 2 Control Bldg East Corridor, Cold Lab, and A-43965 7A, B 2 Adjacent Rooms, El 112 9A, B Switchgear Access Hallway A-43965 35A, B 1 V20 Page 16 of 20 SNC LANTE. I HATH IPg 87 of 114 DOUMNTTILE IDOCUMENT NUMBER: Version No: FIRE PROCEDUREI 34AB-X43-001

-2 15.0 ATTACHMENT 2 Attachment Page TITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 3 OF 4 DIESEL GENERATOR BUILDING DG Building Hallway DG 2A Battery Room DG 1 B Battery Room DG 2C Battery Room DG 2A Day Tank Room DG 1 B Day Tank Room DG 2C Day Tank Room DG 2A Engine Room DG 1B Engine Room DG 2C Engine Room DG 2A SWGR Room 2E DG lB SWGR Room 2F DG 2C SWGR Room 2G PREFIRE PLAN DWG #A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 SliT#5A, B 19A, B 11A, B 23A, B 18A, B 10A, B 22A, B 20A, B 12A, B 24A, B 21A, B 25A, B 26A, B ANALYZED SAFE SHUTDOWN PATH 1 and 2 2 1 and 2 1 2 1 and 2 1 2 1 and 2 1 2 2 1 YARD Cooling Towers Intake Structure Plant Service Water Valve Pit 2A Plant Service Water Valve Pit 2B Condensate Storage Tank Area Nitrogen Storage Tank Area 500KV Reactor Switchyard Main 500 KV Switchyard Auxiliary Boiler Circ Water Pump PIT Radwaste Dilution Valve Pit Diesel 2A Fuel Oil Storage Tank Diesel 20 Fuel Oil Storage Tank A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 A-43966 77A, B 79A, B, C, D 27A, B 50A, B 51A, B 44A, B 42A, B 84A, B 82A, B 61A, B 53A, B 59A, B 73A, B 73A, B 1 and 2 1 and 2 2 1 2 1 and 2 1 and 2 2 N/A 2 2 2 1 V20 Page 17 of 20 SNC LAN E.I. HTCHI IPg 88 of 114 DOCMEN TTLE IDOCUMENT NUMBER:I Version No: FIRE PROCEDURE 34AB-X43-00 1-2 J 15.0 ATTACHMENT 2_ Attachment Page TITLE: PRE FIRE PLANS AND SAFE SHUTDOWN PATHS UNIT 2 J 4 OF 4 PREFIRE PLAN DWG #ANALYZED SAFE SHUTDOWN PATH REACTOR BUILDING SHT#Div I RHR and Core Spray NE Corner Room Div II RHR and Core Spray SE Corner Room CRD Corner Room RClC Room HPCI Room Torus Room -South Half Torus Room -North Half 130 Ft Elev -South 130 Ft Elev -North Recirc ASD Room 2A Recirc ASD Room 2B RWCU Pump A Room RWCU Pump B Room 158 Elev South -Working Floor 158 Elev North 164 Ft Elev HVAC Room Fuel Pool Cooling Heat Exchanger Fuel Pool and RWCU Precoat Equip Area 185 Ft Supply Fan Room 185 Ft Working Floor 185 Ft HVAC Room SBGT Room A SBGT Room B 203 Ft Elevation 203 Ft Elevation Refuel Floor Drywell A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 A-43965 99A, B 2 101AB 1 102AB 1 100A.,B 2 103A.,B 1 105A. B 1 104AB 2 107AB 1 106A, B 2 113A, B 1land 2 114A, B 1land 2 111A, B 1 111A, B 1 110A, B 1 109A, B 2 112A, B 1 116A, B 1 116A, B 1 118A, B 1 116A, B117A,B 1 118AB 1 115A, B 1 115A, B 1 122A, B 1 120A,B 121A,B 1 123A, B 1land 2 104A,B 105A,B 1 and 2 (Torus Area Only)108A, B 1 Main Steam Chase TURBINE BUILDING Turbine Bldg Fire Area 2101 164 Ft Elev Turbine Deck and other Fire Area 0101 Turbine Building Below Turbine Deck West Cableway Stairways Turbine Deck East Cableway A-43965 A-43965 49A, B 87-90A, B A-43965 A-43965 A-43965 A-43965 A-43965 124-1 32A, 133-1 36A, N/A 128A, B N/A 134A, B 43A, B B B 2 1 2 2 2 2 1 V20 Page 18 of 20 SNC LANTE. I HATH 1Pg 90 of 114 DOCMEN TTLE IDOCUMENT NUMBER: Version No: FIRE PROCEDUREI 34AB-X43-001-2 15.0 ATTACHMENT 4 Attachment Page TITLE: SAFE SHUTDOWN COMPONENT LIST PATH 1 1 OF 6 1.0 PATHWAY I TO SHUTDOWN 1.1 Systems Required 1.2.1 RHR, Pump A, RHR Service Water Pump A 1.2.2 RCIC 1.2.3 SRVs 1.2.4 Plant Service Water, Pump A 1.2.5 Emergency Room Coolers 1.2.6 RPV Instrumentation 1.2.7 Containment Instrumentation 1.2.8 Drywell Air (Nitrogen System, Drywell Pneumatic System)1.2.9 Diesel Generator 2A and Associated Electrical Equipment 1.2.10 MSIVs, Inboard 1.2.11 Core Spray Loop A (for spurious ADS WHEN RHR Loop "A" NOT available) 1.2.12 Diesel Building Ventilation 1.2.13 Intake Structure Ventilation 1.2 System Components 1.2.1 RHR, Pump A and RHR Service Water, Pump A Required Normal PATH 1 MPL No Mode SSD Mode 2E11-C001A OFF ON 2E11-C002A OFF ON 2E11-F003A 0 0 2E 11-F004A 0 0 2E11-F006A C C 2E11-F007A 0 VAR 2E1l-F010 C C 2E11-F011A C C 2E11-F015A C 0 2E11-F016A C C 2E11-F017A 0 0 2E11-F026A C C 2E11-F028A C C 2E11-F047A 0 0 2E11-F048A 0 VAR 2E11-F065A 0 0 Required Normal PATH 1 MPL No Mod._._e SSD Mode 2E11-F068A C VAR 2E11-F073A C C 2E1 1-F104A C C 2E11-F119A C C 2E11-K600A ON ON 2E11-K603A ON ON 2E11-N007A ON ON 2E11-N015A ON ON 2E11-N017A C 0 2E11-N017C C 0 2E11-N082A ON ON 2E11-N104A ON ON 2E11-N682A C VAR 2E11-R600A ON ON 2E11-R602A ON ON 2E11-R603A ON ON V20 Page 19 of 20 SNC LANTE. I HATH IPg 96 of 114 DOCMEN TTLE IDOCUMENT NUMBER: Version No: FIRE PROCEDURE 34AB-X43-001-2 15.0 ATTACHMENT 5 Attachment Page TITLE: SAFE SHUTDOWN COMPONENT LIST PATH 2 I OF 7 2.0 PATHWAY 2 TO SHUTDOWN 2.1 Systems Required 2.2.1 RHR, Pump B, RHR Service Water Pump B 2.2.2 Emergency Room Coolers 2.2.3 Plant Service Water, Pump B 2.2.4 RPV Instrumentation 2.2.5 Containment Instrumentation 2.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)2.2.7 HPCI 2.2.8 Diesel Generator 2C and Associated Electrical Equipment 2.2.9 Core Spray, Loop B (for spurious ADS WHEN RHR Loop "B" NOT[ available) 2.2.10 SRVs 2.2.11 MSIVs, Outboard 2.2.12 Diesel Building Ventilation 2.2.13 Intake Structure Ventilation V20 Page 20 of 20 SNC LANTE. I HATH IPg 103 of 114 DOCMET ITE:DOCUMENT NUMBER: Version No: FIRE PROCEDURE 34AB-X43-001-2 15.0 ATTACHMENT 6 Attachment Page TITLE: SAFE SHUTDOWN COMPONENT LIST PATH 3 1OF 7 3.0 PATHWAY 3 TO SHUTDOWN (REMOTE SHUTDOWN SYSTEMS)3.1 Systems Required 3.2.1 RHR, Pump B, RHR Service Water Pump B 3.2.2 Emergency Room Coolers 3.2.3 Plant Service Water, Pump B 3.2.4 RPV Instrumentation 3.2.5 Containment Instrumentation 3.2.6 Drywell Air (Nitrogen System, Drywell Pneumatic System)3.2.7 RCIC 3.2.8 Diesel Generators 2A and 2C and Associated Electrical Equipment 3.2.9 SRVs 3.2.10 MSIVs, Inboard 3.2.11 Diesel Building Ventilation 3.2.12 Intake Structure Ventilation V21 Page 1 of 1 4. ITheMinmumSteam Cooling RPV Water Level for Hatch is: -180 inches. (Both 5. 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 shape prior to Reactor shutdown.c. The temperature of the water injected into the RPV is 1 00 0 F.6. Plant-specific data required to calculate the Minimum Steam Cooling RPV Water Level is as follows: a. Minimum active fuel length fraction which must be covered to maintain peak clad temperature below 1 500 0 F with injection.

b. Active fuel length c. Water level at the bottom of the active fuel E. Minimum Zero-Injection RPV Water Level (LT 31) (LCT 31)1. The Minimum Zero-Injection RPV Water Level is defined to be the lowest RPV water level at which the covered portion of the Reactor core will generate sufficient steam to preclude any clad temperature in the uncovered portion of the core form exceeding 1 800 0 F. This Water Level is utilized to preclude significant fuel damage and 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 shape prior to Reactor shutdown.c. No water is injected into the RPV.EOP-CURVES-LP-20306 Ver 3.0 GRAPH 2 V22 Page 1 of 2 UNIT 1 HEAT CAPACITY TEMPERATURE LIMIT 0[-(i-TORUS WATER LEVEL (in)NOTE: May use SPDS Emergency Displays in place of this Graph.* Safe operating is below the applicable pressure line.

V22 Page 2 of 2 SGRAPH 2 Heat Capacity Temperature Limit E I-260 240 220 2O00 180 160 140 120._'C')I..'I C')0R a-x.I 80 98 120 140 160 180 193200 Torus Water Level (in)Note: May use SPDS in place of this GraphREQUIRED if above curve for existing RPV press EOP-CURVES-20306 FIG 2 Page 61 of 75 V23 Page 1 of 4 Mare Condenser Offgas 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Condenser Offgas LCO 3.7.6 tiT e gross gamma actvity rate of the noble gases measured at the main condenser 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 air ejector (SJAE) in operation.

APPLICABILITY:

ACTIONS___________

_____ ___CONDITION REOUIRED ACTION COMPL=ETION TIME A. Gross gamma activity rate A.1 Restore gross gamma 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months of the noble gases not activity rate of the noble within limit, gases to limit.B8 Required Action and B. 1 Isolate all main steam 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion lines Time not met.OR 8.2 Isolate SJAE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ORR B.3.1 Be in MODE 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B,3.2 Be in MODE 4. 36 hoots HATCH UNIT 2 3.7-16 HATC UNI 2 37-16Amendment No. 135 CD CD 0 (0 CD N, 0-9 CD V23, Page 4 of 4 SU3 Reactor coolant activity greater than Technical Specification allowable limits.Operating Mode: Power Operation Startup Hot Standby Hot Shutdown (1 OR 2)Emergency Action Levels: 1. Pretreatment Radiation Monitor reading greater than 240,000 pCi/sec for greater than 60 minutes.According to Tech. Spec. Bases 3. 7.6 page B3. 7-31 and Tech. Spec. section 3. 7.6 page 3. 7-16, the gross gamma activity rate of the noble gases measured at the main condenser evacuation system pretreatment monitor station shall be <.240mCi/second or <240, O00pCifsecond.

According to 64C1-0CB-006-1/2 procedures the offgas pretreatment radiation monitors are 1/2D1 1-K601 and 1/2D1 1-K602 OR 2. 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 dose equivalent 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. 4.6 page 3.4-11, the specific activity of the reactor coolant shall be limited to DOSE EQUIVALENT 1-131 specific activity 0.2 IJCi/gm. A condition

>0.2 pCi/gm but <2.O IJCi/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 immediate action, V24 Page 1 of 1 RCS Specifi Activity 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 RCS Specific Activity LCO 3.4.6 Thre specifi activty of the reactor coolant shag be limited to DOSE EQUIVALEFNT 1-131 speific activit 0.2 pC~igm.APUCBIUTrY:

MODE 1, MODS 2 and 3 with any m'aui steam line not isolated.ACTIONS CO,,NDmON REQUIRED ACTION COMPLETION TIME A.Reacto colaspecifi NOTE Sacbvtty 0.2 &aCim and LCO 3.0.4.c is apl:iicable.

1 2.0 DOSE lEQUIVALENT 1-131.A.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT 1-131.AND A.2 Restore DOSE EQUIALENT 1-131 to B. Required Ac~tion an B.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion EQUIVALENT 1-131.Time of Cocst A not QR B2.1 Isolate all main steam 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Reactor coolant spcii activity >2.0 DOSE O EQUIVALENT 1-131.B22.1 BeminMODE

3. 12 IurS 8222 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months HATCH UNIT 2 3.4-11 HATH UIT 34-1 AmndmntNo.

210 V25 Page 1 of 6 RCS Operational LEAKAGE B 3.4.4 B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGE BASES BACKGROUND The RCS includes systems and components that contain or transport the coolant to or from the reactor core. The pressure containing components of the RCS and the portions of connecting systems out to and including the isolation valves define the reactor coolant pressure boundary (RCPB). The joints of the RCPB components are welded or bolted.During plant life, the joint and valve interfaces can produce varying amounts of reactor coolant LEAKAGE, through either normal operational wear or mechanical deterioration.

Limits on RCS operational LEAKAGE are required to ensure appropriate action is taken before the integrity of the RCPB is impaired.

This LCO specifies the types and limits of LEAKAGE. This protects the RCS pressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), and GDC 55 of 10 CFR 50, Appendix A (Refs. 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varies widely 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 the unidentified LEAKAGE are necessary to provide the operators quantitative information to permit them to take corrective action should a leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expected from auxiliary systems that cannot be made 100% leaktight.

Leakage from these systems should be detected and isolated from the primary containment atmosphere, if possible, so as not to mask RCS operational LEAKAGE detection.

This LCO deals with protection of the RCPB from degradation and the core from inadequate cooling, in addition to preventing the accident analyses radiation release assumptions from being exceeded.

The consequences of violating this LCO include the possibility of a loss of coolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on the SAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. The normally expected background LEAKAGE due to equipment design (continued)

HATCH UNIT 1 .-3RVSO B 3.4-13 REVISION 0 V25 Page 2 of 6 RCS Operational LEAKAGE B 3.4.4 BASES APPLICABLE and the detection capability of the instrumentation for determining SAFETY ANALYSES system LEAKAGE were also considered.

The evidence from (continued) experiments suggests that, for LEAKAGE even greater than the specified unidentified LEAKAGE limits, the probability is small that the imperfection or crack associated with such LEAKAGE would grow rapidly.The unidentified LEAKAGE flow limit allows time for corrective action before the RCPB could be significantly compromised.

The 5 gpm limit is a small fraction of the calculated flow from a critical crack in the primary system piping. Crack behavior from experimental programs (Refs. 4 and 5) shows that leakage rates of hundreds of gallons per minute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failure mechanism of intergranular stress corrosion cracking (IGSCC) that produces tight cracks. This flow increase limit is capable of providing an early warning of such deterioration.

No applicable safety analysis assumes the total LEAKAGE limit. The total LEAKAGE limit considers RCS inventory makeup capability and drywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC Policy Statement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to: a. Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material degradation.

LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE. Violation of this LCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.b. Unidentified LEAKAGE The 5 gpm of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment air monitoring and drywell sump level monitoring equipment canI (continued)

HATCH UNIT 1 B341 EIIN5 B 3.4-14 REVISION 59 V25 Page 3 of 6 RCS Operational LEAKAGE B 3.4.4 BASES LCO b. Unidentified LEAKAGE (continued) detect within a reasonable time period. Violation of this LCO could result in continued degradation of the RCPB.c. Total LEAKAGE The total LEAKAGE limit is based on a reasonable minimum detectable amount. The limit also accounts for LEAKAGE from known sources (identified LEAKAGE).

Violation of this LCO indicates an unexpected amount of LEAKAGE and, therefore, could indicate new or additional degradation in an RCPB component or system.d. Unidentified LEAKAGE Increase An unidentified LEAKAGE increase of > 2 gpm within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period indicates a potential flaw in the RCPB and must be quickly evaluated to determine the source and extent of the LEAKAGE. The increase is measured relative to the steady state value; temporary changes in LEAKAGE rate as a result of transient conditions (e.g., startup) are not considered.

As such, the 2 gpm increase limit is only applicable in MODE 1 when operating pressures and temperatures are established.

Violation of this LCO could result 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 the reactor is pressurized.

In MODES 4 and 5, RCS operational LEAKAGE limits are not required since the reactor is not pressurized and stresses in the RCPB materials and potential for LEAKAGE are reduced.ACTIONS A._I With RCS unidentified or total LEAKAGE greater than the limits, actions must be taken to reduce the leak. Because the LEAKAGE limits are conservatively below the LEAKAGE that would constitute a critical crack size, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is allowed to reduce the LEAKAGE rates before the reactor must be shut down. If an unidentified LEAKAGE (continued)

HATCH UNIT 1 .-5RVSO B 3.4-15 REVISION 0 V25 Page 4 of 6 RCS Operational LEAKAGE B 3.4.4 B 3.4 REACTOR COOLANT SYSTEM (RCS)B 3.4.4 RCS Operational LEAKAGE BASES BACKGROUND The RCS includes systems and components that contain or transport the coolant to or from the reactor core. The pressure containing components of the RCS and the portions of connecting systems out to and including the isolation valves define the reactor coolant pressure boundary (RCPB). The joints of the RCPB components are welded or bolted.During plant life, the joint and valve interfaces can produce varying amounts of reactor coolant LEAKAGE, through either normal operational wear or mechanical deterioration.

Limits on RCS operational LEAKAGE are required to ensure appropriate action is taken before the integrity of the RCPB is impaired.

This LCO specifies the types and limits of LEAKAGE. This protects the RCS pressure boundary described in 10 CFR 50.2, 10 CFR 50.55a(c), and GDC 55 of 10 CFR 50, Appendix A (References 1, 2, and 3).The safety significance of RCS LEAKAGE from the RCPB varies widely 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 the unidentified LEAKAGE are necessary to provide the operators quantitative information to permit them to take corrective action should a leak occur that is detrimental to the safety of the facility or the public.A limited amount of leakage inside primary containment is expected from auxiliary systems that cannot be made 100% leaktight.

Leakage from these systems should be detected and isolated from the primary containment atmosphere, if possible, so as not to mask RCS operational LEAKAGE detection.

This LCO deals with protection of the RCPB from degradation andthe core from inadequate cooling, in addition to preventing the accident analyses radiation release assumptions from being exceeded.

The consequences of violating this LCO include the possibility of a loss of coolant accident.APPLICABLE The allowable RCS operational LEAKAGE limits are based on the SAFETY ANALYSES predicted and experimentally observed behavior of pipe cracks. The normally expected background LEAKAGE due to equipment design (continued)

HATCH UNIT 2 B341 EIIN7 B 3.4-14 REVISION 77 I V25 Page 5 of 6 RCS Operational LEAKAGE B 3.4.4 BASES APPLICABLE and the detection capability of the instrumentation for determining SAFETY ANALYSES system LEAKAGE were also considered.

The evidence from (continued) experiments suggests that, for LEAKAGE even greater than the specified unidentified LEAKAGE limits, the probability is small that the imperfection or crack associated with such LEAKAGE would grow rapidly.The unidentified LEAKAGE flow limit allows time for corrective action before the RCPB could be significantly compromised.

The 5 gpm limit is a small fraction of the calculated flow from a critical crack in the primary system piping. Crack behavior from experimental programs (Refs. 4 and 5) shows that leakage rates of hundreds of gallons per minute will precede crack instability (Ref. 6).The low limit on increase in unidentified LEAKAGE assumes a failure mechanism of intergranular stress corrosion cracking (IGSCC) that produces tight cracks. This flow increase limit is capable of providing an early warning of such deterioration.

No applicable safety analysis assumes the total LEAKAGE limit. The total LEAKAGE limit considers RCS inventory makeup capability and drywell floor sump capacity.RCS operational LEAKAGE satisfies Criterion 2 of the NRC Policy Statement (Ref. 9).LCO RCS operational LEAKAGE shall be limited to: a. Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material degradation.

LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE. Violation of this LCO could result in continued degradation of the RCPB.LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.b. Unidentified LEAKAGE The 5 gpm of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment air monitoring and drywell sump level monitoring equipment can (continued)

HATCH UNIT 2 B341 EIIN7 B 3.4-15 REVISION 77 I V25 Page 6 of 6 RCS Operational LEAKAGE B 3.4.4 BASES LCO LCOb. Unidentified LEAKAGE (continued) detect within a reasonable time period. Violation of this LCO could result in continued degradation of the RCPB.c. Total LEAKAGE The total LEAKAGE limit is based on a reasonable minimum detectable amount. The limit also accounts for LEAKAGE from known sources (identified LEAKAGE).

Violation of this LCO indicates an unexpected amount of LEAKAGE and, therefore, could indicate new or additional degradation in' an RCPB component or system.d. Unidentified LEAKAGE Increase An unidentified LEAKAGE increase of > 2 gpm within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period indicates a potential flaw in the RCPB and must be quickly evaluated to determine the source and extent of the LEAKAGE. The increase is measured relative to the steady state value; temporary changes in LEAKAGE rate as a result of transient conditions (e.g., startup) are not considered.

As such, the 2 gpm increase limit is only applicable in MODE 1 when operating pressures and temperatures are established.

Violation of this LCO could result 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 the reactor is pressurized.

In MODES 4 and 5, RCS operational LEAKAGE limits are not required since the reactor is not pressurized and stresses in the RCPB 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 LEAKAGE limits are conservatively below the LEAKAGE that would constitute a critical crack size, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is allowed to reduce the LEAKAGE rates before the reactor must be shut down. If an unidentified LEAKAGE (continued)

HATCH UNIT 28341REION7 B 3.4-16 REVISION 77 V1 8 Page 1 of 10 SOUTHERN NUCLEARI PLANT El. HATCH PAGE 9 OF 30 DOUMNTTILE t DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAINMENT CONTROL t 34AB-T22-003-1 5.14 ATTACHMENT 2 ATT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1G31-R604) 1 OF 1 Max Normal Max Safe SECONDARY CONTAINMENT TEMP Operating Operating on 1H11-P614, 1G31-R604 Value Value 0 F o 158' ELEVATION AREA (RWCU)101 B Pump Room (1G31-N016D) 150 212.5 102 B Pump Room DIFF (1G31-N022C/1G31-N023C) 67 98 103 Hx Room (1G31-N016B) 150 212.5 104 Hx Room DIFF (1G31-N022D/1G31-N023D) 67 98 105 Ph Sep Rm (1G31-N016F) 150 212.5 106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98 NORTHEAST DIAGONAL AREA 107 RHR/CS B (1E11-N009B) 150 212.5 108 RHR/CS B DIFF(1E11-N030B/1E11-N029B) 40 98 HPCl ROOM AREA 109 Emer Area CIr (1E41-N030B) 167.5 245 110 HPCI VENT AIR DIFF (1E41-N029B/1E41-N028B)

NA NA (not used)RCIC ROOM AREA 111 Emer Area CIr (1 E5I-N023B) 167.5 310 112 RCIC VENT AIR DIFF (1E51-N022B/1E51-N021 B) NA NA (not used)TORUS ROOM AREA 113 Southwest Wall (1E51-N025B) 167.5 212.5 114 Northeast Wall (1E51-N025D) 167.5 212.5 115 VENT AIR DIFF (1E51-N027B/1E51-N026B) 42 102 116 VENT AIR DIFF (1 E51-N027D/1 E51-N026D) 42 102 HPCI PIPE PENETRATION ROOM 117 1E41-N046B 150 212.5 Posted 1 H11-P614 MGR-0009 Rev 5.0 V1 8 Page 2 of 10 PAGE 10 OF 30 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-1 5.14 ATTACHMENT 3 ATTACH. PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (1 G31 -R608) 1 OF 1 Max Normal Max Safe SECONDARY CONTAINMENT TEMP Operating Operating on 1IH11-P614, 1G31-R608 Value Value oF o 158' ELEVATION AREA (RWGU)101 A Pump Room (1G31-N016C) 150 212.5 102 A Pump Room DIFF (1G31-N022B/1G31-N023B) 67 98 103 Hx Room (1G31-N016E) 150 212.5 104 Hx Room DIFF (1G31-N022A/1G31-N023A) 67 98 105 Phase Sep Rm (1G31-N016A) 150 212.5 106 Phase Sep Rm DIFF (1G31-N022E/1G31-N023E) 67 98 SOUTHEAST DIAGONAL AREA 107 RHR/CS A (lE1 1-N009A) 150 212.5 108 RHRICS A DIFF (1EI11-N030A/1 E11-N029A) 40 98 HPCI ROOM AREA 109 Pump Room (1E41-N024) 167.5 245 110 Emer Area CIr (1 E41 -N030A) 167.5 245 111 HPCl VENT AIR DIFF (1 E41-N029A/11E41-N028A)

NA NA (not used)_________

RClC ROOM AREA 112 Pump Room (1E51-N011) 167.5 310 113 Emer Area CIr (1E51-N023A) 167.5 310 114 RCIC VENT AIR DIFF (1 E51-N022A/1 E51-N021A)

NA NA (not used)TORUS ROOM AREA 115 West Wall (1E51-N025A) 167.5 212.5 116 Southeast Wall (1E51-N025C) 167.5 212.5 117 VENT AIR DIFF (1 E51-NO26AI1 E51-N027A) 42 102 118 VENT AIR DIFF (1E51-N026C/1 E51-N027C) 42 102 MAIN STEAM LINE TUNNEL AREA 119 Main Stm TnI 1B21-N014 192.5 300 120 1B21-N016AN0O16B DIFF 60 150 HPCI PIPE PENETRATION ROOM 150 212.5 121 1E41-N046A Posted 1 H11-P614 MGR-0009 Rev 5.0 V1 8 Page 3 of 10 PAGE 27 OF 30 SOUTHERN NUCLEAR PLANT E.I. HATCH DOUMNTTILE

]DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14 ATTACHMENT 9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2 Max Max SECONDARY CONTAINMENT TEMPNoml Sf on IHI1-P614, 1G31-R604 0 158' ELEVATION AREA (RWCU)101 B Pump Rm (1G31-N016D) 150 212.5 102 B Pump Rm DIFF (1G31-N022C/1G31-N023C) 67 98 103 Hx Rm (1G31-N016B) 150 212.5 104 Hx Rm DIFF (1G31-N022D/1G31-N023D) 67 98 105 Ph Sep Rm (1G31-N016F) 150 212.5 106 Ph Sep Rm DIFF (1G31-N022F/1G31-N023F) 67 98 NORTHEAST DIAGONAL AREA 107 RHR/CS B(1E11-N009B) 150 212.5 108 RHR/CS B DIFF (1E11-N030B/1E11-N029B) 40 98 HPCI ROOM AREA 109 Emer Area CIr (1E41-N030B) 167.5 245 RCIC ROOM AREA 111 Emer Area Clr (1 E51-N023B) 167.5 310 TORUS ROOM AREA 113 Southwest Wall (1E51-N025B) 167.5 212.5 114 Northeast Wall (1 E51-N025D) 167.5 212.5 115 Vent Air DIFF (1E51-N027B/1E51-N026B) 42 102 116 Vent Air DIFF (1E51-N027D/1E51-N026D) 42 102 HPCl PIPE PENETRATION ROOM 117 1E41-N046B 150 212.5 RDG RDG 1 2 3 Reference 34AB-T22-003-1 MGR-0009 Rev 5.0 Vi18 Page 4 of 10 PAGE 28 OF 30 SOUTHERN NUCLEARI PLANT E.I. HATCH DOUMNTTILE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-1 5.14 ATTACHMENT

-9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2 SECONDARY CONTAINMENT TEMP Max Max on 1H11-P614, 1G31-R608 Normal Safe 158' ELEVATION AREA (RWCU)101 A Pump Rm (1G31-N016C) 150 212 102 A Pump Rm DIFF (1G31-N022BI1E51-N023B) 67 98 103 Hx Rm (1G31-N016E) 150 212.5 104 Hx Rm DIFF (1G31-N022A/1G31-N023A) 67 98 105 Phase Sep Rm (1G31-N016A) 150 212.5 106 Phase Sep Rm DIFF(1G31-N022E/1G31-N023E) 67 98 SOUTHEAST DIAGONAL AREA 107 RHR/CS A(1E11-N009A) 150 212.5 108 RHR/CS A DIFF (1E11-N030A/1E11-N029A) 40 98 HPCl ROOM AREA 109 Pump Rm (1E41-N024) 167.5 245 110 EmerArea Clr(1E41-N030A) 167.5 245 RCIC ROOM AREA 112 Pump Rm (1E51-N011) 167.5 310 113 EmerArea CIr (1E51-N023A) 167.5 310 TORUS ROOM AREA 115 West Wall (1E51-N025A) 167.5 212.5 116 Southeast Wall (1E51-NO25C) 167.5 212.5 117 VENT AIR DIFF (1E51-N026A11E51-N027A) 42 102 118 VENT AIR DIFF (1E51-N026C/1E51-N027C) 42 102 MAIN STEAM LINE TUNNEL AREA 119 Main Stm Tnl (1B21-N014) 192.5 300 120 1B21-N016A/N016B DIFF 60 150 HPCI PIPE PENETRATION ROOM 121 1E41-N046A 150 212.5 I/RDG RDG RDG 1 2 3 I________Iec 4B-2-0-MGR-0009 Rev 5.0 V18 Page 5 of 10 PAGE 29 OF 30 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMET ITE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL 34AB-T22-003-1 5.14 ATTACHMENT 10 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT PARAMETERS 1 OF 1 I max 14" aow8rTelw.

Ir Irt' 3TabowSTe~ev.

t#' aovSe lteev.DIAGONALAREA 150 212.5 I.IV ROOMAIEA wI' h svIo"fl vi" IT 71e, CO4hNMEN REFA RADIATIONIMONITORS I [g~11.SS 1211UV~jteVae IEREL FLO(F AREA 1Reathe.J iee (1D21-KG00A) 50 1000 2 a u(IO141-01 B) 50 10(00 3 P.uuI o(1O21-K60lD) 50 1000 4 Dr~weIl 50 1000 5 SpeltFtmlPool&New~uelStcrage(1D21.K501M 50 1000 5RB20Wor~ru(1D21K0 X) 50 7 SpentFuel PoC DeuinvEquip{1O21.01C) 150 I1Q000 eFu.PocDsrmin, Pmn(1D21.K17) 50 10 ___9 R81irWokArea(1D214K601K) 50 1 000 10 RxbSarjiRzdkue (ID214K601L) 50 1 000)11 50 IOQ00 12 NothCRVHCU(1021-IQD1P) 50 I1000 14 R8130N.E~odinku(1D21.K601G) 50 I1000 15 50 ]1000 __ELEVATION SOUTH AREA 16 50 1000 17 SoutthCAOHCJ(1D2FH(0tN) 50 1000 _18 RCCEEupSWDmgna(1O21.KO1V) 50 I1000 NORfN"TI~LAOA AREA 19 CR)PumpiWOIagvnI(1D21.(801W) 50 I1000 NOfES G4LAREA 20 CS&RJIRN~.Edg(1D21-KIE01Y) 50 1000 SOUT~fJST ENA-(NAL ARE --_ -21 CS&Rk-IlS,,EDigoza{IDT2.K6O1R) 50 1 (000!J7 ELEVATION AREA ET 22 HFOTuwtmieAlui1D214t01T) 150 I10(00 1OP114S-~1933~

I l=l 1 I 34AB-T22-O03-1 OPS-1 933 MGR-0009 Rev 5.0 V1 8 Page 6 of 10 PAGE 9 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOUMNTTILE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NMENT CONTROL I 34AB-T22-003-2 4.2 ATTACHMENT 2 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 1 (2G31-R604)_________

MAX NORMAL MAX SAFE SECONDARY CONTAINMENT TEMP ON 2H11-P614, OPERATING OPERATING 2G31-R604 VALUE VALUE°F °F 158' ELEVATION AREA (RWCU)101. B pump room (2G31-N016B) 150 215 102. B pump room DIFF (2G31-N023B/2G31-N022B) 67 99 103. Hx Room (2G31-N016D) 150 215 104. Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99 185' ELEVATION AREA (RWCU)105. Valve Nest (2G31-N016F) 150 215 106. Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 99 SOUTHEAST DIAGONAL AREA 107. RHR/CS B (2E11-N009B) 150 190 108. RHR/CS B DIFF (2E11-N030B/2E11-N029B) 40 74 HPCI ROOM AREA 109. Emer area clr (2E41-N030B) 167.5 245 110. HPCl vent air DIFF (2E41-N029B/2E41-N028B)

NA NA (not used)______

____RClC ROOM AREA 111. Emer Area CIr (2E51-N023B) 167.5 310 112. RCIC vent air DIFF (2E51-N022B/2E51-N021B)

NA NA (not used)______

____TORUS ROOM AREA 113. Northwest Wall (2E51-N025B) 167.5 212.5 114. Southeast Wall (2E51-N025D) 167.5 212.5 115. Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98 116. Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98 HPCI PIPE PENETRATION ROOM 117. 2E41-N046B 167.5 212.5 Vi18 Page 7 of 10 PAGE 10 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMEN TTLE IDOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL I 34AB-T22-003-2 4.2 ATTACHMENT 3 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES (2G31 -R608) 1 OF 1 MAX NORMAL MAX SAFE SECONDARY CONTAINMENT TEMP ON 2H1 1-P614, OPERATING OPERATING 2G31-R608 VALUE VALUE°F °F 158' ELEVATION AREA (RWCU)101. A Pump Room (2G31-N016A) 150 215 102. A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 99 103. Hx Room (2G31-N016C) 150 215 104. Hx Room DIFF (2G31-N023C/2G31-N022C) 67 99 105. Phase Sep Rm (2G31-N016E) 150 215 106. Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 99 NORTHEAST DIAGONAL AREA 107. RHR/CS A (2E1 1-N009A) 150 215 108. RHR/CS A DIFF (2E11-N030AN2E11-N029A) 40 74 HPCI ROOM AREA 109. Pump Rm (2E41-N024) 167.5 245 110. Emer Area CIr (2E41-N03OA) 167.5 245 111. HPCI Vent Air DIFF (2E41-N029A/2E41-N028A)

NA NA (not used)__________

RCIC ROOM AREA 112. Pump Rm (2E51-N011) 167.5 310 113. Emer Area CIr (2E51-N023A) 167.5 310 114. RCIC Vent Air DIFF (2E51-N022A12E51-N021A)

NA NA (not used)TORUS ROOM AREA 115. West Wall (2E51-N025A) 167.5 212.5 116. Northeast Wall (2E51-N025C) 167.5 212.5 117. Torus Vent Air DIFF (2E51-N027A/2E51-N026A) 42 98 118. Torus Vent Air DIFF (2E51-N027C/2E51-N026C) 42 98 MAIN STEAM LINE TUNNEL AREA 119. Main Steam Tunnel (2B21-N014) 192.5 310 120. Main Stm Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150 HPCI PIPE PENETRATION ROOM 121. 2E41 -N046A 167.5 212.5 V18 Page 8 of 10 PAGE 30 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMET ITE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2 ATTACHMENT

_9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 1 OF 2 SECONDARY CONTAINMENT TEMPMMA on 2H11-P614, 2G31-R604 NORMALj SAFE 158' ELEVATION AREA (RWCU)101 B pump room (2G31-N016B) 150 215 102 B pump room DIFF (2G31-N023B/2G31-N022B) 67 99 103 Hx Room (2G31-NO16D) 150 215 104 Hx Room DIFF (2G31-N023D/2G31-N022D) 67 99 185' ELEVATION AREA (RWCU)105 Valve Nest (2G31-N016F) 150 215 106 Valve Nest DIFF (2G31-N023F/2G31-N022F) 67 9 SOUTHEAST DIAGONAL AREA 107 RHR/CS B (2E11-N009B) 150 J190 108 RHR/CS B DIFF (2E1 1-N030B/2G31-N029B) 40 J 74 HPCI ROOM AREA 109 Emer Area CIr (2E41-N030B)

I67.5 245 RCIC ROOM AREA 111 Emer Area CIr (2E51-N023B)

16. 1 TORUS ROOM AREA 113 Northwest Wall (2E51-N025B) 167.5 212.5 114 Southeast Wall (2E51-N025D) 167.5 212.5 115 Torus vent air DIFF (2E51-N027B/2E51-N026B) 42 98 116 Torus vent air DIFF (2E51-N027D/2E51-N026D) 42 98 HPCI PIPE PENETRATION ROOM 117 2E41-N046B Ii7.5I 212.5 Values displayed in the NORM column (green) represent the values at 100% rated thermal power, summertime conditions.

POSTED AT 2H1 1-P614 SOUTHERN NUCLEAR PLANT E.I. HATCH Vi18 Page 9 of 10 PAGE 31 OF 37 DOCMET ITE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAINMENT CONTROL 34AB-T22-003-2 4.2 ATTACHMENT 9 ATTACHMENT PAGE: TITLE: SECONDARY CONTAINMENT OPERATING TEMPERATURES 2 OF 2 SECONDARY CONTAINMENT TEMP MAX MAX on 2H11-P614, 2G31-R608 NORMAL[ SAFE 158' ELEVATION AREA (RWCU)101 A Pump Room (2G31-N016A) 150 21 102 A Pump Room DIFF (2G31-N023A/2G31-N022A) 67 9 103 Hx Room (2G31-N016C) 150 21 104 Hx Room DIFF (2G31-N023C/2G31-N022C) 67 9 105 Phase Sep Rm (2G31-N016E) 150 21 106 Phase Sep Rm DIFF (2G31-N023E/2G31-N022E) 67 9 NORTHEAST DIAGONAL AREA 107 RHR/CS A (2E1 1-N009A) 150 21 108 RHR/CS A DIFF (2E11-N030AI2E11-N029A) 40 174 HPCl ROOM AREA 109 Pump Rm (2E41-N024) 167.5 245 110 Emer Area Clr(2E41-N030A) 167.5/ 245 RClC ROOM AREA 112_Pump Rm_(2E51-N011) 167.5 _310 113 Emer Area Clr (2E51-N023A) 167.5 310 TORUS ROOM AREA 115 West Wall (2E51-N025A) 167.5 212.5 116 Northeast Wall (2E51-N025C) 167.5 212.5 117 Torus vent air DIFF (2E51-N027A12E51-N026A) 42 98 118 Torus vent air DIFF (2E51-N027C/2E51-N026C) 42 98 MAIN STEAM LINE TUNNEL AREA 119 Main Steam Tunnel (2B21-N014) 192.5 310 120 Main Steam Tunnel DIFF (2B21-N016B/2B21-N016A) 70 150 RDG RDG 1 RDG 1 2 3-B_HPCl PIPE PENETRATION ROOM I 121 2E41,N046A

[167.5 212.5_Values displayed in the NORM column (green) represent the values at 100% rated thermal power, summertime conditions.

POSTED AT 2H1 1-P614 V1 8 Page 1 0 of 10 PAGE 35 OF 37 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCMEN TILE:DOCUMENT NUMBER: VERSION NO: SECONDARY CONTAI NM ENT CONTROL 34AB-T22-003-2 4.2 ATTACHMENT 1"1 ATTACHMENT PAGE: TITLE: SECONDARY CONTAI NMENT PARAMETERS 1 OF 1 Table 4 o'9tA~hG~iWAfli I I C0NbleN 5 A 101 102 AREA WATER LEVELS Max Nanul MaxSafe.___ 4" r/5T'sia 33 isv .1.AREA 4"iow ST ealeion!$"o8T 1ev'.4icvelTelwian 27.bovel7'elw.

diov.STal.vglwi t#' above $'t' 4" isve 8'uleiion 14" isy rr sh, 4 aov 57' ekydon tt" above 37' .ev.Table 6 ARIA MOR10.3 yaw aw S UUHd113 l 51-N058) I167.5 212.5 114 Sou WlbeI (2E514NU50) l167.5 212.5 116 ToqusM VtOIFF 42 9 01 A Pw~own%2;G31.#408A o mpRoooN2G314 t3Phu Sep Rm(2m1.N01E)

Va 150 67'so 57 150 Ri Va 215 99 215 98 215 1 Reac had (2D21-K601A) 50 1Q000 3 SfouIlo&NswFu l~g.(2f21.KBO1M) 50 1000 4 ahFboor(2D214(SI11K) 5o 10o0 G Reeor Vesse!RFloor (2Q21.K811 L) 50 1Q000 63 (2D214,SO1T) 50 10]00 7 HV o¢W 50 100 8 Spn u olPsaea 50 1000 9 RB 18 qelegIoor(2O21..KO0R) 50 1000 10 R81W Samispuue t.lme(221.(8O1S) 50 1Q000 I'I R818 cou~rol pa-.(2O21-K601U) 15O t000__13 S reaIW (2D21.(501D) 50 1000__15Dean um eupmntronara 50 1000__

`1000 1307 ELEVATION ARE.A (NSRUThWS N(R11PMB(2T2IMOIF)

L AO RtOA 217 50 .1000 22 RC1S.W4~odgAii(2D21,,K601X) 50 .1000 23 cs&rRls~dagoi(2V214WO1Y) 150 1000O 115 16+7.5 21 215 42 198l34AB-.T22-003-2 OPS-1932 OPS-1 932 V19 Page 1 of 4 PAGE 2 OF 3 SOUTHERN NUCLEAR PLANT E.I. HATCH DOCUMENT TITLE: DOCUMENT NUMBER: VERSION NO: ARP'S FOR CONTROL PANEL 2H1 1-P657, 34AR-657-901-2 I 23.1 ALARM PANEL 1 UNIT 2 2H11-P657

-1 (LEFT)657-001 657-002 657-00.3 557-004 57-005 657-006 657-007 657-008 657-009 657-019 657-020 657-021 57-02 657-023 657-024 657-025 657-026 657-027 657-037 657 -03 6 57-03;;57-040 6 7-041 657-042 657-043 657-044 657-045 657-055 657-05S G57 057 657-058 -5705 657-060 657-061 657-062 657-063 657-07 657-074 657-075 657-0Th 657-77 657-07 657-079 657-080 657-081 657-091 57 0 2 657-093 557-094 657-095 657 096 65-097 657-098 657-099 2H11-P657

-1 (RIGHT)657-010 657-011 G57-012 657-013 657-014 657-015 657-016 657-017 657-018 657-028 ss57-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036 657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054 657-064 65 7-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072 657-082 657-0B3 65-084 657-085 657-086 657-087 657-088 657-089 657-090 657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108 Level Of Use ARPs CONTINUOUS ALL REFERENCE None INFO None Vi19 Page 2 of 4 1.0 IDENTIFICATION:

ALARM PANEL 657__ _______SEISMIC* INSTRUMENTATION TRIGGERED DEVICE: SETPOINT: 2L51-N022 0.08 g horizontal, 0.54 g vertical 2L51 -N024 0.18 g horizontal, 0.063 vertical 2.0 CONDITION:

3.0 CLASSIFICATION

[ EQUIPMENT STATUS Motion has been detected in Unit 2 Reactor Building on4.LOAIN elevation 87' or 185' 4 H0 LOCATION 5.0 OPERATOR ACTIONS: 5.1 At Panel 1 Hi11-P701, check for further indications of a seismic event by 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). LII 5.2 Refer to Seismic Instrumentation Earthquake Response Manual, SX-18271, for guidance in analyzing seismic data. LI 5.3 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon.

LI 5.4 Enter NMP-EP-1 10, Emergency Classification Determination and Initial Action. LI 5.5 Refer to Unit 2 FSAR, Figure 3.7A-7 for required actions. LI 6.0 CAUSES: Seismic event

7.0 REFERENCES

8.0 TECH. SPECS./TRMIODCMIFHA:

7.1 H-16319, Seismic Measurement Equip Control TRM T3.3.6 Seismic Monitoring Panel & Instrumentation.

Instrumentation 7.2 H-17978, Seismic Measurement Equip Sys L51 Panel HI11-P701 Wiring & Ext. Conn Dia.7.3 H-27169, Seismic Measurement Equip Sys 2651 Panel Hi11-P701 Wiring & Ext. Conn Dia.34AR-657-048-2 VER 4.1 MGR-0048 Ver. 5.0 Vi19 Page 3 of 4 UNIT 1 IH11-P657

-1 (RIGHT)657-010 657-011 657-012 657-013 657-014 657-015 657-016 657-017 657-018 657-028 657-029 657-030 657-031 657-032 657-033 657-034 657-035 657-036 657-046 657-047 657-048 657-049 657-050 657-051 657-052 657-053 657-054 657-064 657-065 657-066 657-067 657-068 657-069 657-070 657-071 657-072 657-082 657-083 657-084 657-085 657-086 657-087 657-088 657-089 657-090 657-100 657-101 657-102 657-103 657-104 657-105 657-106 657-107 657-108 RECORDS There are no records generated by the procedure COMMITMENTS NONE MGR-0001 Ver. 4 V19 Page 4 of 4 1.0 IDENTIFICATION:

ALARM PANEL 657________

SEISMIC PEAK SHCKRECORDERJ DEVICE: SETPOINT: 1 L51-Vbc-R620 Not available 5.0 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). El 5.2 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 El 5.3 Refer to SX-18271, Seismic Instrumentation Earthquake Response Manual, for guidance in analyzing seismic data. El 5.4 Enter 34AB-Y22-002-0, Naturally Occurring Phenomenon.