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MC 252 #1 – Macondo Prospect OCS-G-32306 Well Control Simulation Results April 29, 2010.

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Presentation on theme: "MC 252 #1 – Macondo Prospect OCS-G-32306 Well Control Simulation Results April 29, 2010."— Presentation transcript:

1 MC 252 #1 – Macondo Prospect OCS-G Well Control Simulation Results April 29, 2010

2 Case 1 – Surface Exit Up The Riser 7” x 9-7/8” Casing Flowpath; No Drillstring Oil RateGas Rate 138,300 bpd194 mmscf Assumptions: Drillpipe was ejected out during the unloading process. Worst-Case Surface Scenario

3 Case 2 – Surface Exit Up The Riser 7” x 9-7/8” Casing Flowpath; Drillstring in Rotary Table Oil RateGas Rate 110,000 bpd155 mmscf Assumptions: Drillpipe remains in tact and provides choke at the subsea BOP.

4 Case 3 – Surface Exit Up The Riser 7” x 9-7/8” Casing Flowpath; Drillstring Dropped into 7” Casing Oil RateGas Rate 93,000 bpd131 mmscf Assumptions: Drillpipe was cut out during the unloading process and hangs up in the top of the 7” casing due to the 5-1/2” drill pipe tool joints being 7” OD. ~147 ft 6-5/8” drill pipe sticking out

5 Case 4 – Surface Exit Up The Riser 7” x 9-7/8” Casing Annulus Flowpath Oil RateGas Rate 64,000 bpd91 mmscf Assumptions: Wellhead packer does not provide isolation.

6 Case 5 – Seafloor Exit 7” x 9-7/8” Casing Flowpath; No Drillstring Oil RateGas Rate 146,000 bpd147 mmscf Assumptions: Drillpipe was ejected out during the unloading process. Worst-Case Unrestricted Through Casing Subsea Scenario

7 Case 6 – Seafloor Exit 7” x 9-7/8” Casing Flowpath; Drillstring Dropped into 7” Casing Oil RateGas Rate 77,000 bpd78 mmscf Assumptions: Drillpipe was cut out during the unloading process and hangs up in the top of the 7” casing due to the 5-1/2” drill pipe tool joints being 7” OD; acts as a choke on the flow. ~147 ft 6-5/8” drill pipe sticking out

8 Case 7 – Seafloor Exit 7” x 9-7/8” Casing Annulus Flowpath Oil RateGas Rate 69,500 bpd70 mmscf Assumptions: Drillpipe inside Riser with LMRP disconnected at subsea BOP Worst-Case Restricted Seafloor Annulus Flow

9 Case 8 – Seafloor Exit 7” x 9-7/8” Casing Annulus Flowpath ID Oil RateGas Rate 5.625” 51, ” 42, ” 23, ” 8, ” 1,000 2 Assumptions: Crushed Riser splits 5-1/2” drill pipe at subsea BOP and allows flow out 6-5/8” drill pipe.

10 CaseOil RateGas RateBOEComments Flow up the 7” x 9-7/8” Casing String 1138, ,550No Drillpipe 2110,000 Surface 393,000 Dropped Flow behind the 7” x 9-7/8” Casing Annulus 464, ,207 22” Exposed Well Control Simulation Results Surface Exit Up The Riser

11 CaseOil RateGas RateBOEComments Flow up the 7” x 9-7/8” Casing String 5146, ,180No Drillpipe 677, Dropped Flow behind the 7” x 9-7/8” Casing Annulus 769, ,96722” Exposed 8 Well Control Simulation Results Seafloor 4,992 ft Water Depth

12 CaseOil RateGas Rate BOEComments 8-1/2” Open M56 Sand Package RW1257, ,500No Drillpipe Surface Well Control Simulation Results Relief Well - Surface Exit Up Riser

13 Oil RatesGas RatesMud WeightKill Rate Flow up the 7” x 9-7/8” Casing StringNo Drillstring 146,000 bpd147 mmscf 15 ppg28 bpm 16 ppg26 bpm 20 ppg18 bpm 77,000 bpd 78 mmscf Dropped 16 ppg15 bpm Flow behind the 7” x 9-7/8” Casing Annulus 69,500 bpd70 mmscf 15 ppg18 bpm 16 ppg16 bpm 20 ppg10 bpm Dynamic Kill Simulation Results Seafloor 4,992 ft Water Depth

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