calvert cliffs gsi-191 program - nrc: home page11/18/2016 supplemental presentation slides for...

From: Greene, Ken:(GenCo-Nuc)To: Guzman, RichardSubject: [External_Sender] FW: T/H Analysis PresentationDate: Friday, November 18, 2016 10:17:37 AMAttachments: RI GSI-191 TH Analysis Results.pdf

Rich,Good morning. Attached is a presentation covering information Steve Smith, NRC, had requested tosee.Have a good Thanksgiving.

From: Sellers, Craig:(Contractor - GenCo-Nuc) Sent: Friday, November 18, 2016 9:29 AMTo: Greene, Ken:(GenCo-Nuc)Cc: Drake, Andre S:(GenCo-Nuc); Salehi, Matthew:(GenCo-Nuc); Haydin, John S:(GenCo-Nuc); Lauver,Doug:(GenCo-Nuc)Subject: T/H Analysis Presentation Ken, Please submit the attached presentation to the Calvert Cliffs NRC Project Manager. Inform him thatSteve Smith (NRC Staff) wanted to see this data. Thanks, Craig___________________________Craig D. SellersProject ManagerGSI-191 Resolution/GL 2004-02 ClosureCalvert Cliffs Nuclear Power Plant(o) 410.495.4272 - Calvert Cliffs(c) 410.610.1164___________________________

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Calvert Cliffs GSI-191 Program Thermal Hydraulic Analysis of Containment Response Calculation CA10199 November 18, 2016

Thermal Hydraulic Analysis of Containment

• Investigate Sump Temperature and Containment Pressure

– Large Break LOCA Events

– LOCA Scenarios Presented

• DEGB Cold Leg,

- 2 Trains of ESF (Maximum SI) – CCX

- Single Train of ESF (Minimum SI) - CCI

• DEGB Hot Leg,

- 2 Trains of ESF (Maximum SI) – HHX

- Single Train of ESF (Minimum SI) – HHI

- 2 ft2 Break, Single Train of ESF – H2I

Calvert Cliffs GSI-191 Containment Response T/H Analyses 1

Thermal Hydraulic Analysis of Containment (Cont.)

• Containment Response Scenarios Evaluated – Scenario A: 2 Containment Air Coolers (CACs) Operating

• Determine if containment pressure is reduced to 2.8 psig prior to sump fluid temperature reducing to 140°F.

• If both Containment Spray (CS) pumps operating, secure one pump at 2.8 psig. – Scenario B: 4 CACs Operating

• Determine how quickly the containment pressure could drop to sub-atmospheric conditions in the strainer.

• If both Containment Spray (CS) pumps operating, secure one pump at 2.8 psig. – Scenario C: 4 CACs Operating

• Determine, for the case where no single failures have occurred (4 CACs and 2 Containment Spray Pumps operating), if the containment response profile remains below the EQ profile.

• When the first CS Pump is secured (at 2.8 psig), the other CS Pump is lost for 30 minutes and two (2) CACs are lost indefinitely.

– Scenario D: Repeat Scenario C with the following change: • When the first CS Pump is secured (at 2.8 psig), the other CS Pump is lost for 30 minutes.

– Scenario E: Repeat Scenario C with the following change: • When the first CS Pump is secured (at 2.8 psig) and one HPSI pump is also secured, the

other CS Pump and the other HPSI pump are lost for 30 minutes. Two CACs are also assumed to be lost indefinitely.


Typical Containment Pressure Profile


0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Con

tain

men

t Pre

ssur

e (p

sig)

Time (s)

RAS

CS Pump Trip

Pressure Reduction due to reduction in M&E release and heat removal by heat sinks

Pressure Increase due to increase in M&E release from RCS reflood spillage

Pressure Reduction due to heat removal by CS and CACs

Typical Containment Air Temperature Profile


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

RAS

CS Pump Trip

Temp Reduction due to heat removal by CS and CACs Temp Reduction due

to reduction in M&E release and heat removal by heat sinks

Typical Sump Temperature Profile – Hot Leg Break


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CS Pump Trip

RAS

Typical Sump Temperature Profile – Cold Leg Break


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CS Pump Trip

RAS

Temp Reduction due to SI spillage from break

Scenario A – Containment Pressure


0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Con

tain

men

t Pre

ssur

e (p

sig)

Time (s)

CCX

CCI

HHX

HHI

H2I

Scenario A – Containment Air Temperature


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

CCI

HHX

HHI

H2I

Scenario A – Sump Temperature


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

CCI

HHX

HHI

H2I

Scenario B – Containment Pressure


0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

CCI

HHX

HHI

H2I

Scenario B – Containment Air Temperature


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

CCI

HHX

HHI

H2I

Scenario B – Sump Temperature


100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

CCI

HHX

HHI

H2I

Thermal Hydraulic Analysis Results

• 2 CS pumps + 2 CACs – Hot Leg Break

• Time to 140°F = 108.3 hours • Time to 2.8 psig = 47.2 hours • Time to secure pump = 61.1 hours • Pressure @ 140°F = 1.98 psig

– Cold Leg Break • Time to 140°F = 77.8 hours • Time to 2.8 psig = 63.9 hours • Time to secure pump = 13.9 hours • Pressure @ 140°F = 2.58 psig





Scenario C – Containment Pressure & Temperature


0

10

20

30

40

50

60

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

HHX

ES-014(EQ)

100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

HHX

ES-014(EQ)

Scenario D – Containment Pressure & Temperature


0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

HHX

ES-014

100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Tem

pera

ture

(F)

Time (s)

CCXHHXES-014

Scenario E – Containment Pressure & Temperature


0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

HHX

ES-014 (EQ)

100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

HHX

ES-014 (EQ)

Calvert Cliffs GSI-191 Program

















Calvert Cliffs GSI-191 Program Thermal Hydraulic Analysis of Containment Response Calculation CA10199 November 18, 2016


• Investigate Sump Temperature and Containment Pressure

– Large Break LOCA Events

– LOCA Scenarios Presented

• DEGB Cold Leg,

- 2 Trains of ESF (Maximum SI) – CCX

- Single Train of ESF (Minimum SI) - CCI

• DEGB Hot Leg,

- 2 Trains of ESF (Maximum SI) – HHX

- Single Train of ESF (Minimum SI) – HHI

- 2 ft2 Break, Single Train of ESF – H2I



• Containment Response Scenarios Evaluated – Scenario A: 2 Containment Air Coolers (CACs) Operating

• Determine if containment pressure is reduced to 2.8 psig prior to sump fluid temperature reducing to 140°F.

• If both Containment Spray (CS) pumps operating, secure one pump at 2.8 psig. – Scenario B: 4 CACs Operating

• Determine how quickly the containment pressure could drop to sub-atmospheric conditions in the strainer.

• If both Containment Spray (CS) pumps operating, secure one pump at 2.8 psig. – Scenario C: 4 CACs Operating

• Determine, for the case where no single failures have occurred (4 CACs and 2 Containment Spray Pumps operating), if the containment response profile remains below the EQ profile.

• When the first CS Pump is secured (at 2.8 psig), the other CS Pump is lost for 30 minutes and two (2) CACs are lost indefinitely.

– Scenario D: Repeat Scenario C with the following change: • When the first CS Pump is secured (at 2.8 psig), the other CS Pump is lost for 30 minutes.

– Scenario E: Repeat Scenario C with the following change: • When the first CS Pump is secured (at 2.8 psig) and one HPSI pump is also secured, the

other CS Pump and the other HPSI pump are lost for 30 minutes. Two CACs are also assumed to be lost indefinitely.




0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Con

tain

men

t Pre

ssur

e (p

sig)

Time (s)

RAS

CS Pump Trip

Pressure Reduction due to reduction in M&E release and heat removal by heat sinks

Pressure Increase due to increase in M&E release from RCS reflood spillage

Pressure Reduction due to heat removal by CS and CACs



100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

RAS

CS Pump Trip

Temp Reduction due to heat removal by CS and CACs Temp Reduction due

to reduction in M&E release and heat removal by heat sinks



100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CS Pump Trip

RAS



100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CS Pump Trip

RAS

Temp Reduction due to SI spillage from break



0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Con

tain

men

t Pre

ssur

e (p

sig)

Time (s)

CCX

CCI

HHX

HHI

H2I



100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

CCI

HHX

HHI

H2I



0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

CCI

HHX

HHI

H2I



100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+00 1.E+01 1.E+02 1.E+03 1.E+04 1.E+05 1.E+06 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

CCI

HHX

HHI

H2I



0

10

20

30

40

50

60

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

HHX

ES-014(EQ)

100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

HHX

ES-014(EQ)



0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

HHX

ES-014

100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Tem

pera

ture

(F)

Time (s)

CCXHHXES-014



0

5

10

15

20

25

30

35

40

45

50

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Pres

sure

(ps

ig)

Time (s)

CCX

HHX

ES-014 (EQ)

100

120

140

160

180

200

220

240

260

280

300

1.E-01 1.E+01 1.E+03 1.E+05 1.E+07

Tem

pera

ture

(F)

Time (s)

CCX

HHX

ES-014 (EQ)

11.18.16 (KGreene) Email T_H Analysis PresentationCC GSI-191 TH Analysis Results Supplement 11.18.16Calvert Cliffs GSI-191 ProgramThermal Hydraulic Analysis of ContainmentThermal Hydraulic Analysis of Containment (Cont.)Typical Containment Pressure ProfileTypical Containment Air Temperature ProfileTypical Sump Temperature Profile – Hot Leg BreakTypical Sump Temperature Profile – Cold Leg BreakScenario A – Containment PressureScenario A – Containment Air TemperatureScenario A – Sump TemperatureScenario B – Containment PressureScenario B – Containment Air TemperatureScenario B – Sump TemperatureThermal Hydraulic Analysis ResultsScenario C – Containment Pressure & TemperatureScenario D – Containment Pressure & TemperatureScenario E – Containment Pressure & Temperature

calvert cliffs gsi-191 program - nrc: home page11/18/2016 supplemental presentation slides for...

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