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					                                                                    Well Control Toolbox

               Operator:     ADTI / PALACE                Job #:         YLA0557           Rig ID:     TODCO 46
           Area / Block:     BAYOU CARLIN                 Client:       PALACE OP.          Date:       4-Feb-06
        ADTI Supervisor:            0                    Well ID:           0              Driller:         0

       Casing Drillpipe                  Total    Pit      %
TIME   Pressure Pressure   Gas   SPM    Strokes Volumn   Flow                                REMARKS
                                                                          Well Control Toolbox
             Operator:        ADTI / PALACE                         Job #:               YLA0557                             Rig ID:              TODCO 46
         Area / Block:        BAYOU CARLIN                          Client:             PALACE OP.                            Date:                4-Feb-06
      ADTI Supervisor:                                             Well ID:                                                  Driller:

                  RIG INFO                                 KICK DATA                               CASING SHOE TEST                                      RESULTS
     Water Depth                       8   Total Measured Depth - TMD            7500   Casing Shoe MD         4500        ft.          Mud Weight Increase         0.7 ppg
     Rotary Table Elevation           32   Total Vertical Depth - TVD            7500   Casing Shoe TVD        4500        ft.          Kill Weight Mud            10.8 ppg
     Annular -16-3/4" 5M           17.33   SIDPP                        250     psi     L.O.T. Pressure        1150        psi          Barite to Weight Up        918 Sacks
     Top Rams - 5" DP              23.34   SICP                         350     psi     Test Mud Weight          9.5       ppg          Calculated ICP             250 psi
     Middle Rams - Blind            25.4   Pit Gain                     10.0   bbls.    Equivalent Mud Wt.      14.4       ppg          Calculated FCP                0 psi
     Bottom Rams - 5" DP           30.91   MW in Hole - MW              10.1   ppg      MACP                   1006        psi          Est Height of Influx        75 ft.
     Wellhead - 16-3/4" 5M         32.45   Surface Pit Volume           613    bbls.                                                    Max Anticipated
                                           Barite on Board             1500 sacks.                                                      Surface Pressure           484 psi
           Slow Pump Rate Depth                        SPR MW                PPG                                                        Probable Kick Type       Gas
             Slow Pump Rates                   20         30         40       bbl/stk               DIRECTIONAL DATA                          SURFACE STACK STROKES
           Slow Pump Pressures                  0          0          0       0.1170       1st Kick Off Point TVD - KOP1                Surface to Bit            1011 Strokes
            SUBSEA WELL INFO                                                              2nd Kick Off Point TVD - KOP2                 Open Hole Strokes         4721 Strokes
             Choke Line Friction                         0                                      2nd Kick Off Point (TMD)                Surface to Shoe           5732 Strokes
                                                                                                                                        Bottoms Up Strokes       12208 Strokes
          ANNULAR CAPACITIES               Casing ID   DP OD        Top       Bottom      Interval     bbl/ft    bbls   Cum bbls        Surface to Surface       13219 Strokes
 1   5" DP x 16" Casing                      15.010      5.000           0       4500          4500    0.1947       876     876                SUBSEA STACK STROKES                  Length
 2   5" DP X 14-3/4" Open Hole               14.750      5.000        4500       6374          1874    0.1871       351    1227         Bottoms Up on Choke           0 Strokes    HWT      918.00
 3   5" HWDP x 14.75" Open Hole              14.750      5.000        6374       7298           924    0.1871       173    1400         Surface to Surface                           DC     215.00
 4   8" DC x 14.75" Open Hole                14.750      7.750        7298       7395            97    0.1531        15    1414         on Choke                      0 Strokes   Bottom Depth
 5   9" DC x 14.75" Open Hole                14.750      9.000        7395       7500           105    0.1327        14    1428         Surface to Surface                       DP Btm      6367
 6                                                                       0                         0   0.0000         0    1428         up Riser                      0 Strokes HWT Btm      7285
 7                                                                       0                         0   0.0000         0    1428         Bottoms Up Strokes                           TD      7500
 8                                                                       0                         0   0.0000         0    1428         up Riser                      0 Strokes
 9                                                                                                 0   0.0000         0    1428
10                                                                                                 0   0.0000         0    1428
             SUBSEA WELL INFO                                Internal Data Check TD =          7500    = OK                1428             "ADJUSTED" DRILLPIPE ID's
     Drillpipe x Riser                                                0             0             0    0.0000       0.0         0.0     Size        Weight           Grade      ID (")
     Choke Line                            0.000    NA                0            50            50    0.0000       0.0         0.0       5          19.5              E        4.240
     Kill Line                                      NA                0            50            50    0.0000       0.0         0.0      4.5         16.6              E        3.822
                                 Total Annular Volume (thru choke line)          1428             Total Annular Volume        1428       3.5         13.3              E        2.757
                                                                                                                                  0     2.875        10.4              E        2.150
         DRILLSTRING CAPACITIES            String OD String ID     Top     Bottom         Interval     bbl/ft    bbls      Cum bbls       5          19.5              X        4.216
 1   5" DP x 16" Casing                         5.000    4.185           0     4500            4500    0.0170        77         77       4.5         16.6              X        3.813
 2   5" DP X 14-3/4" Open Hole                  5.000    4.185       4500      6374            1874    0.0170        32        108       3.5         13.3              X        2.746
 3   5" HWDP x 14.75" Open Hole                 5.000    3.000       6374      7298             924    0.0087         8        117      2.875        10.4              X        2.138
 4   8" DC x 14.75" Open Hole                   7.750    2.875       7298      7395              97    0.0080         1        117        5          19.5              G        4.205
 5   9" DC x 14.75" Open Hole                   9.000    3.000       7395      7500             105    0.0087         1        118       4.5         16.6              G        3.814
 6                                              0.000                    0        0                0   0.0000         0        118       3.5         13.3              G        2.740
 7   0                                          0.000                    0        0                0   0.0000         0        118      2.875        10.4              G        2.138
 8   0                                          0.000                    0        0                0   0.0000         0        118        5          19.5              S        4.185
 9   0                                          0.000                    0        0                0   0.0000         0        118       4.5         16.6              S        3.801
10   0                                          0.000                    0        0                0   0.0000         0        118       3.5         13.3              S        2.726
             SUBSEA WELL INFO                              Internal Data Check TD =            7500    = OK                             2.875        10.4              S        2.123
     Drillpipe x Riser                         0.000      4.185           0         0             0     0.0170         0           0
                                                                                         Total Drillstring Volume (bbls)         118

                                                                                                                                            0.0              125.0   113468.5      484
                                                                                                                                            0.0               11.0   106114.1      337
                                                                                      Well Control Toolbox                                                                           SURFACE STACK

         Operator:             ADTI / PALACE                              Job #:             YLA0557                             Rig ID:             TODCO 46                        SUBSEA STACK
      Area / Block:            BAYOU CARLIN                               Client:           PALACE OP.                            Date:               4-Feb-06
ADTI Supervisor:                          0                              Well ID:                 0                              Driller:                 0
Driller's Method Kill Sheet                                                         SURFACE STACK
     SIDPP         250 psi                       MACP        1006 psi
     SICP          350 psi                                                                                  Drillpipe Pressure Schedule
          30 spm         Desired Slow Circulating Rate                                                             (2nd Circulation)
           0 psi         Slow Pump Presure

DP Pressure Schedule (2nd Circ.)
                                                                                       1380
     Strokes    PSI                  Minutes
                                                                                       1360
           0    1370                    0
                                                                                       1340
 1        83    1355 Enter              3
                                                                                       1320
 2       167    1340 Actual             6
                                                                                       1300
 3       250    1326    ICP             8
 4       334    1311 Here              11
                                                                                       1280
 5       418    1296                   14                                              1260
 6       503    1281                   17                                              1240
 7       588    1266                   20                                              1220
 8       672    1251                   22                                              1200
 9       757    1236                   25                                              1180
10       842    1221                   28                                                     0           200          400           600          800          1000         1200
11       926    1206                   31                                                                                 Pump Strokes to Bit
12      1011    1191 = FCP             34

                          RESULTS                                                                                PROCEDURE (1st Circulation)
     Mud Weight Increase                   0.7   ppg                         1      Initiate a Kick Log (pressures, times, etc.)
     Kill Weight Mud                      10.8   ppg                         2      Start pump and bring pump to speed following Pump-Start Procedure.
     Barite to Weight Up                   918   Sacks                              Surface BOPs
     Calculated ICP                        250   psi                                Start pump and maintain casing pressure constant at SICP value.              350 psi
     Calculated FCP                          0   psi                                Subsea BOPs
     Est Height of Influx                   75   ft                                 Start pump and allow casing pressure to reduce by choke line friction.                  0 psi
     Max Anticipated                                                                OR: Start pump and maintain kill monitor pressure constant at SICP value.
     Surface Pressure                   484 psi                              3      When pump is up to kill rate - Record correct Initial Circulating Pressure on drillpipe gauge.
     Probable Kick Type               Gas                                    4      Continue holding constant ICP and constant pump rate until all influx out of annulus.
             SURFACE STACK STROKES                        Minutes                                                                                                       1370 psi
     Surface to Bit           1011 Strokes                   34                     2nd Circulation
     Open Hole Strokes        4721 Strokes                  157              5      When KWM is ready, zero counter, Follow Pump-Start Procedure as above.
     Surface to Shoe          5732 Strokes                  191              6      Drillpipe pressure should be at (or nearly equal to) previous ICP.
     Bottoms Up Strokes      12208 Strokes                  407              7      Use choke to control DP pressure according to Pressure Schedule until kill mud at bit.
     Surface to Surface      13219 Strokes                  441              8      Continue holding constant FCP and constant pump rate until kill mud returns to surface.
             SUBSEA STACK STROKES                         Minutes            9      Stop pump and check that well is dead.
     Bottoms Up on Choke         0 Strokes                          0
     Surface to Surface
     on Choke                                 0 Strokes             0
     Surface to Surface
     up Riser                                 0 Strokes             0
     Bottoms Up Strokes
     up Riser                                 0 Strokes             0



         250   psi       SIDPP
         350   psi       SICP
        10.7   ppg       Kill Weight Mud
       0.117   bbl/stk   Pump Output

         250 psi         Calculated Initial Circulating Pressure - ICP
           0 psi         Calculated Final Circulating Pressure - FCP

        1011 stks        Surface to Bit            33.69 mins.
        4721 stks        Bit to Shoe              157.38 mins.
       12208 stks        Bottoms-up               406.93 mins.


        Gas              Probable Kick Type
        484 psi          Max Anticipated Surface Pressure

          20         0           0
          30         0           0
          40         0           0
                                                                                           Well Control Toolbox                                                                 SURFACE STACK

       Operator:               ADTI / PALACE                         Job #:             YLA0557                           Rig ID:              TODCO 46                         SUBSEA STACK
   Area / Block:               BAYOU CARLIN                          Client:           PALACE OP.                          Date:                4-Feb-06
ADTI Supervisor:                      0                             Well ID:               0                              Driller:                  0

Wait & Weight Method Kill Sheet                                                SURFACE STACK
     SIDPP        250 psi                      MACP        1006    psi
     SICP         350 psi
                                                                                                  Drillpipe Pressure Schedule
          30 spm         Desired Slow Circulating Rate
           0 psi         Slow Pump Presure
           DP Pressure Schedule                                                 1560
     Strokes PSI             Minutes                                            1540
           0 1550                0                                              1520
 1        83 1536 Enter          3                                              1500
 2       167 1522 Actual         6                                              1480
 3       250 1509     ICP        8                                              1460
 4       334 1495    Here       11                                              1440
 5       418 1481               14                                              1420
 6       503 1467               17
                                                                                1400
 7       588 1453               20
                                                                                1380
 8       672 1439               22
 9       757 1425               25                                              1360
10       842 1411               28                                                     0          200          400          600          800          1000         1200
11       926 1397               31                                                                                Pump Strokes to Bit
12      1011 1383 = FCP         34

                        RESULTS                                                                                      PROCEDURE
     Mud Weight Increase            0.7 ppg                               1 Initiate a Kick Log (pressures, times, etc.)
     Kill Weight Mud              10.8 ppg                                2 Start pump and bring pump to speed following Pump-Start Procedure.
     Barite to Weight Up           918 Sacks                                Surface BOPs
     Calculated ICP                250 psi                                  Start pump and maintain casing pressure constant at SICP value.                  350 psi
     Calculated FCP                   0 psi                                 Subsea BOPs
     Est Height of Influx            75 ft                                  Start pump and allow casing pressure to reduce by choke line friction.                       0 psi
     Max Anticipated                                                        OR: Start pump and maintain kill monitor pressure constant at SICP value.
     Surface Pressure              337 psi                                3 When kill weight is ready, zero counter and bring pump on line following Pump-Start Procedure as above.
     Probable Kick Type         Gas                                       4 When pump is up to kill rate read and record correct Initial Circulating Pressure on drillpipe gauge.
              SURFACE STACK STROKES             Minutes                     Drillpipe pressure should be at (or nearly equal to) the pre-determined ICP. If the difference is 100 psi
     Surface to Bit              1011 Strokes      34                       or greater then use the measured value and recalculate the DP Pressure Schedule                  1550 psi.
     Open Hole Strokes           4721 Strokes     157                     5 Use choke to control DP pressure according to Pressure Schedule (ICP to FCP) until kill mud at bit.
     Surface to Shoe             5732 Strokes     191                     6 Continue holding constant FCP and constant pump rate until kill mud returns to surface.
     Bottoms Up Strokes         12208 Strokes     407                     7 Stop pump and check that well is dead.
     Surface to Surface         13219 Strokes     441
              SUBSEA STACK STROKES              Minutes
     Bottoms Up on Choke              0 Strokes       0
     Surface to Surface
     on Choke                         0 Strokes       0
     Surface to Surface
     up Riser                         0 Strokes       0
     Bottoms Up Strokes
     up Riser                         0 Strokes       0




         250   psi       SIDPP
         350   psi       SICP
        10.7   ppg       Kill Weight Mud
       0.117   bbl/stk   Pump Output
         250   psi       Calculated Initial Circulating Pressure - ICP
           0   psi       Calculated Final Circulating Pressure - FCP

        1011 stks        Surface to Bit            0.56 hrs
        4721 stks        Bit to Shoe               2.62 hrs
       12208 stks        Bottoms-up                6.78 hrs




        Gas              Probable Kick Type
        337 psi          Maximum Anticipated Surface Pressure



          20         0           0
          30         0           0
          40         0           0
                                                                                                    Well Control Toolbox

                                  Operator:             ADTI / PALACE                        Job #:              YLA0557                             Rig ID:           TODCO 46
                               Area / Block:            BAYOU CARLIN                         Client:            PALACE OP.                            Date:              2/4/06
    ADTI Supervisors:                                            0                          Well ID:                 0                               Driller:               0

Volumetric Procedure for Handling Gas Migration

   Gas migration is indicated by an equal and steady rise in SIDPP and SICP!                                                                         Original SICP =   350 psi
1 Select a Safety Margin and Range to control bottom-hole pressure.
  Recommend: Safety Margin = 100 psi Range = 100 psi              Enter Safety Margin =                                  100 psi            Enter Pressure Range =     100 psi
2 Calculate the Hydrostatic Pressure per bbl of mud in the upper annulus.                                                  Calculated Hydrostatic Pressure per bbl =   2.70 psi/bbl
                                                                                                                                                 5" DP x 16" Casing

3 The Volume to Bleed each Cycle.                                                                                                        Volume to bleed per cycle =   37.1 bbls

4 Allow shut-in casing pressure to increase by the Saftey Margin without bleeding any volume.
5 Allow shut-in casing pressure to increase by the Range without bleeding.
6 Maintain the increased casing pressure constant by bleeding small increments of mud from
  the choke until the Volume per Cycle is bled (measured in a calibrated trip tank).

7 Repeat Steps 6 & 7 until another well control procedure is implemented or gas is at the surface.

                                                                                                       Enter Original Shut-in Casing Pressure =         350 psi
                                               Volumetric Procedure
                                                                                                        Start     Allow to    Cas. psi   Volume     Total
                                                                                                       Casing     Increase     While       To      Volume
                               3000                                                         Cycle        psi       To (psi)   Bleeding    Bleed     Bled
                                                                                              1         350        550       550       37.1     37.1            890
                               2500
       Casing Pressure (psi)




                                                                                              2         550        650       650       37.1     74.1            498
                               2000                                                           3         650        750       750       37.1     111.2           346
                                                                                              4         750        850       850       37.1     148.3           265
                               1500                                                           5         850        950       950       37.1     185.3           214
                                                                                              6         950        1050      1050      37.1     222.4           180
                               1000
                                                                                              7         1050       1150      1150      37.1     259.4           155
                                500                                                           8         1150       1250      1250      37.1     296.5           137
                                                                                              9         1250       1350      1350      37.1     333.6           122
                                 0                                                                                             1450
                                      0.0      100.0          200.0         300.0   400.0                        Casing Pressure and Bleed Schedule
                                                       Volume Bled (bbls)
 0 volume 0.0 pressure
                    350
 1        0.0       550
 2      37.1        550
 3      37.1        650
 4      74.1        650
 5      74.1        750
 6     111.2        750
 7     111.2        850
 8     148.3        850
 9     148.3        950
10     185.3        950
11     185.3       1050
12     222.4       1050
13     222.4       1150
14     259.4       1150
15     259.4       1250
16     296.5       1250
17     296.5       1350
18     333.6       1350
                                                                                  Well Control Toolbox
              Operator:          ADTI / PALACE                               Job #:               YLA0557                              Rig ID:        TODCO 46
          Area / Block:          BAYOU CARLIN                                Client:            PALACE OP.                               Date:         4-Feb-06
   ADTI Supervisors:                      0                                Well ID:                    0                               Driller:             0


Lubrication Procedure Worksheet - Pressure Method
                     Original Shut-in Casing Pressure              350 psi                     Enter Starting Shut-in Casing Pressure (P1) -      800 psi

1 Select a Working Range to control bottom-hole pressure.
                                                                                                           Enter a Working Pressure Range =       100 psi
2 Pump into the closed-in well to increase casing pressure by the Working Range.
                                                                                                      Estimated New Casing Pressure (P2) =        900 psi
   NOTE: In the case of high fluid loss downhole - use the casing pressure                               (Use the stabilized casing pressure
   that stabilizes after injecting the lube mud (may not be possible to use                                        after injecting lube mud!)
   the recommended range).
                                                                                            Actual stabilized casing psi after injection (P2) =   915 psi
3 Allow time for the mud to "lubricate" through the gas (usually 10 - 15 minutes).

4 Bleed GAS, decreasing the casing pressure to the calculated New Casing Pressure value.
                                                                                                    Bleed Gas Off Casing Pressure to (P3) =       699 psi
                   P3 = P1^2 / P2
   NOTE: Ensure that no significant amount of mud is bled. If so, allow additional
   time for the gas to lubricate through the mud (or gas is not all at surface).
   Returns should be routed through the mud gas separator to the trip tank
   and any volume of mud bled back with the gas is recorded and accounted for.

5 Use the New Casing Pressure as the Starting Shut-in Casing Pressure for the next cycle.

6 Repeat steps 2, 3, and 4 for additional cycles until all gas is removed or another procedure is implemented.

   NOTE: It is likely that less and less volume will be lubricated during each additional
   cycle as the process continues. This is due to the reduction in volume of the
   compressible gas.
                                                                                   Well Control Toolbox
              Operator:           ADTI / PALACE                               Job #:                YLA0557                            Rig ID:           TODCO 46
          Area / Block:           BAYOU CARLIN                                Client:             PALACE OP.                            Date:            4-Feb-06
   ADTI Supervisors:                       0                                Well ID:                    0                              Driller:             0

Lubrication Procedure Worksheet - Volume Method
           Original Shut-in Casing Pressure              350 psi
                                                            Enter starting shut-in casing pressure due to gas at surface (P1)-             600 psi

1 Select a Safety Margin and Range to control bottom-hole pressure (Recommend Safety Margin & Range = 100 psi)
                                    Enter Safety Margin =           100 psi                                 Enter Working Range =          100 psi

2 Calculate the Hydrostatic Pressure per Bbl of mud in the upper annulus.                           Hydrostatic Pressure per bbl =        2.70 psi/bbl
                                                                                                                5" DP x 16" Casing
3 Pump into the closed-in well to increase casing pressure by the Safety Margin.

4 Pump into the closed-in well to increase casing pressure by the Working Range.               New Shut-in Casing Pressure (P2) =          700 psi
                                                                                                           (Record actual value)
5 Allow time for the mud to "lubricate" through the gas (usually 10 - 15 minutes).

6 Measure the trip tank and calculate the hydrostatic pressure increase of the mud lubricated for that cycle.
                                                                                      Enter the volume lubricated for cycle =              5.0 bbls

                                                  Hydrostatic Increase = Volume lubricated for cycle x Hydrostatic per bbl =                13 psi

7 Bleed dry gas from the choke to reduce the casing pressure by the range and by the hydrostatic increase.
                                                                                            Casing pressure before bleeding (P2) -         700 psi
                                                                                             First bleed casing back to (P1) value -       600 psi
                                                                                                   Then bleed off the HP increase -        -13 psi
   NOTE: Ensure that no significant amount of mud is bled. If so, allow additional                        Bleed casing pressure to -       587
   time for the gas to lubricate through the mud (or gas is not all at surface).
   Returns should be routed through the mud gas separator to the trip tank
   and any volume of mud bled back with the gas is recorded and accounted for.

8 Repeat steps 4 through 7 for additional cycles until all gas is removed or another procedure is implemented.

   NOTE: It is likely that less and less volume will be lubricated during each additional
   cycle as the process continues. This is due to the reduction in volume of the
   compressible gas.
                                                                               Well Control Toolbox
             Operator:         ADTI / PALACE                              Job #:                YLA0557                             Rig ID:          TODCO 46
         Area / Block:         BAYOU CARLIN                               Client:            PALACE OP.                              Date:           4-Feb-06
   ADTI Supervisors:                      0                             Well ID:                        0                           Driller:            0

Long Term Annular Stripping - Worksheet
                                 Enter the Shut-in Casing Pressure (Pa) =                               350 psi

 1 Select a Working Pressure Range (Pw) to control bottomhole pressure.                                                     Pw =       100 psi
   Recommended Value: Pw = 100 psi

 2 Calculate the hydrostatic pressure per bbl of mud in the upper annulus.               Hydrostatic Pressure per bbl =               2.70 psi/bbl
                                                                                                    5" DP X 14-3/4" Open Hole
   HP / bbl = Mud gradient / Upper annular capacity
 3 Calculate the length of influx when penetrated by the BHA, L1.                                                           L1 =     333.3 ft

   L1 = Influx Volume / OH X DC Capacity            Enter the OH by Collar Capacity =              0.0300 bbl/ft

 4 Calculate the length of the influx in open hole, L2.                                                                     L2 =     200.0 ft

   L2 = Influx Volume / Open Hole Capacity             Enter the Open Hole Capacity =              0.0500 bbl/ft

 5 Calculate the pressure increase due to influx penetration, Ps.                                                           Ps =        57 psi
   Ps = (L1 - L2) x (Mud Gradient - .1)

 6 Calculate the pertinent Strip Tank (Vs) and Trip Tank (Vt) volumes.                                                      Vs =        2.2 bbls
                                                          Enter DP OD being stripped =                       5 inches
   Vs = Closed end pipe displacement per stand                 Enter length per stand =                     90 ft            Vt =     37.1 bbls
   Vt = Working pressure range (Pw) / Upper annular hydrostatic per bbl

 7 Calculate the Pchoke Values.                                                                                         Pchoke1 =      507 psi
                                                                                                                        Pchoke2 =      607 psi
   Pchoke1 = Pa + Pw + Ps           Pchoke2 = Pchoke1 + Pw          Pchoke3 = Pchoke2 + Pw   ....etc.                   Pchoke3 =      707 psi
                                                                                                                        Pchoke4 =      807 psi
   Procedure:
 1 Strip first stand (without bleeding) to allow casing pressure to increase to Pchoke1 value.
 2 Choke operator to bleed as necessary to maintain casing pressure constant at Pchoke value. After each stand,
   drain the stripping volume Vs from the Trip Tank into the Stripping Tank (or alternate). Remember to lower pipe slowly,
   have the floorhands remove pipe burrs from TJs, and remember to fill the string after each stand.
 3 Continue as in Step 2 until a net gain of V2 (volume representing gas migrating) is noted in the Trip Tank. Then close the choke.
 4 Repeat Steps 1 through 3 until on bottom. When on bottom, circulate well dead using the Driller's Method.
                                                                              Well Control Toolbox
                  Operator:   ADTI / PALACE                               Job #:               YLA0557                                                            Rig ID:                 TODCO 46
              Area / Block:   BAYOU CARLIN                             Client:             PALACE OP.                                                              Date:                   4-Feb-06
         ADTI Supervisors:            0                               Well ID:                      0                                                             Driller:                         0

Well Info Summary                         Total Depth     7500 ft                                           Current MW                               10.1 ppg
                                                 TVD      7500 ft                                             Frac MW                                14.4 ppg
           Wellbore Diagram               KOP1 (TVD)         0 ft                                            Shoe TVD                                4500 ft
                                          KOP2 (TVD)         0 ft                                            Shoe MD                                 4500 ft
                                          KOP2 (MD)          0 ft                                       MAASP (psi)                                  1006 psi
    0
          Water               Water
          Depth               Depth
                                                       Subsea Info:                 Riser ID  DP OD            DP ID                                Top          Bottom      DS Vol       An Vol
                                          Drillpipe x Riser                             0.000   0.000            4.185                                    0            0          0            0
                                          Choke Line                                    0.000  NA                0.000                                    0           50          0
  1000                                    Kill Line                                     0.000  NA                0.000                                    0           50          0

                                                Hole Sections (ft - RT)            Annular ID DP OD      DP ID         Top     Bottom DS Vol                                              An Vol
                                          5" DP x 16" Casing                          15.010    5.000        4.185          0     4500     76.6                                             875.6           0
                                          5" DP X 14-3/4" Open Hole                   14.750    5.000        4.185       4500     6374     31.9                                             350.5           0
  2000
                                          5" HWDP x 14.75" Open Hole                  14.750    5.000        3.000       6374     7298       8.1                                            172.9           0
                                          8" DC x 14.75" Open Hole                    14.750    7.750        2.875       7298     7395       0.8                                             14.8           0
                                          9" DC x 14.75" Open Hole                    14.750    9.000        3.000       7395     7500       0.9                                             13.9           0
                                                                                       0.000    0.000        0.000          0        0       0.0                                              0.0           0
  3000                                              0                                  0.000    0.000        0.000          0        0       0.0                                              0.0           0
                                                    0                                  0.000    0.000        0.000          0        0       0.0                                              0.0           0
                                                                                                      Total Drillstring Volume (bbls) -     118                                                             0
                                                                                                                   Total Annular Volume (bbls) -                                            1428                  0
  4000                                                                              SPM 1      SPM 2     SPM 3                                                                                                    0
          Last
                                          Slow Circ. Rates and Pressures                 20        30            40 bbl/stk
          Casin
            g                             Pump # 1                                        0         0             0    0.1170
          Shoe                                                                                                                                                                                                  2.58
  5000                                    Subsea                                                                                                                                                                   0
                                          Through Choke Line                               0            0                                   0                   Kick Tolerance
                                                                                                                                                                Maximum Kick Intensity (ppg)           2.58
                                                                                                                                                                For 0 Volume Influx
  6000                                                    KICK INFORMATION                                                                                      Maximum Kick Volume (bbls)                 NI
                                          Shut-in Drillpipe Pressure                     250 psi                                                                For Swab Condition (0 ppg)
                                          Shut-in Annulus Pressure                       350 psi
                                                                                                                                                                   Kick Tolerance
                                          Pit Gain                                        10 bbls
  7000
                                                                                                                 Max Underbalance (ppg)


                                                                                                                                           3
                                                                                                                                          2.5
                                                                                                                                           2
                                                                                                                                          1.5
  8000                                                                                                                                     1
                                                                                                                                          0.5
                                                                                                                                           0
                                                                                                                                                0         0.2          0.4          0.6      0.8       1

                                                                                                                                                                    Max Kick Vol (bbls)
 Water Depth =           8      RT =    0           0 = Riser length          Riser ID =              0


                 Casing ID   DP OD          Top                  Bottom                    Interval
                                0.000               0                     0                           0
                     15.01      5.000                0                 4500                     4500
6.625               14.750      5.000             4500                 6374                     1874
5.000               14.750      5.000             6374                 7298                      924
5.000               14.750      7.750             7298                 7395                       97
4.000               14.750      9.000             7395                 7500                      105
4.000               14.750      0.000                0                 7500                        0
4.000               14.750      0.000                0                 7500                        0
4.000               14.750      0.000                0                 7500                        0

        50.000      50.000     50.000         50.000         0
        50.000      50.000     50.000         50.000         0
        55.000      45.000     34.990         65.010         0
        55.000      45.000     34.990         65.010      4500
        55.000      45.000     35.250         64.750      4500                     4500               80
        55.000      45.000     35.250         64.750      6374                     4500               20
        55.000      45.000     35.250         64.750      6374
        55.000      45.000     35.250         64.750      7298
        57.750      42.250     35.250         64.750      7298                         8              80
        57.750      42.250     35.250         64.750      7395                         8              20
        59.000      41.000     35.250         64.750      7395
        59.000      41.000     35.250         64.750      7500
        50.000      50.000     50.000         50.000      7500
        50.000      50.000     50.000         50.000      7500
        50.000      50.000     50.000         50.000      7500
        50.000      50.000     50.000         50.000      7500
        50.000      50.000     50.000         50.000      7500
        50.000      50.000     50.000         50.000      7500
                                                           Well Control Toolbox

                Operator:      ADTI / PALACE           Job #:          YLA0557               Rig ID:           TODCO 46
            Area / Block:      BAYOU CARLIN            Client:        PALACE OP.              Date:             4-Feb-06
         ADTI Supervisor:                             Well ID:                               Driller:

                    MAXIMUM ALLOWABLE CASING PRESSURES                                     Water Depth                          8
                                CASING SIZE    16"                                         Rotary Table Elevation - RT         32
                                                                                           Annular - 13-5/8" 5M                17
                                                                                           Top Rams - 5" DP                    23
CASING TVD                  4500     FT              CASING GRADE       HCN80      BTC     Middle Rams - Blind                 25
CASING MEASURED DEPTH       4500     FT              CASING WEIGHT       84.0     LBS/FT   Bottom Rams - 5" DP                 31
TEST PRESSURE               1150    PSI              CSG BURST 100%      4330      PSI     Wellhead - 13-5/8" 5M               32
TEST MUD WEIGHT              9.5    PPG              BURST @ 70%         3031      PSI     Mudline Hanger
EQUIVALENT MUD WEIGHT       14.41   PPG              COLLAPSE 100%       2090      PSI
                                                                                                      PREVIOUS CASING
MUD WT   MAX ALLOWABLE PRESS                         MUD WT      MAX ALLOWABLE PRESS       Casing Size            24
   9.5           1150    PSI                          12.6               425     PSI       Casing Grade         WELD        BTC
   9.6           1127    PSI                          12.7               401     PSI       Casing Weight         156       LBS/FT
   9.7           1103    PSI                          12.8               378     PSI       Casing Burst 100%                PSI
   9.8           1080    PSI                          12.9               354     PSI       Casing Burst@ 70%                PSI
   9.9           1056    PSI                          13.0               331     PSI       Collapse 100%                    PSI
  10.0           1033    PSI                          13.1               308     PSI
  10.1           1010    PSI                          13.2               284     PSI
  10.2            986    PSI                          13.3               261     PSI
  10.3            963    PSI                          13.4               237     PSI
  10.4            939    PSI                          13.5               214     PSI
  10.5            916    PSI                          13.6               191     PSI
  10.6            893    PSI                          13.7               167     PSI
  10.7            869    PSI                          13.8               144     PSI
  10.8            846    PSI                          13.9               120     PSI
  10.9            822    PSI                          14.0                97     PSI
  11.0            799    PSI                          14.1                74     PSI
  11.1            776    PSI                          14.2                50     PSI
  11.2            752    PSI                          14.3                27     PSI
  11.3            729    PSI                          14.4                3      PSI
  11.4            705    PSI                          14.4                       PSI
  11.5            682    PSI                          14.4                       PSI
  11.6            659    PSI                          14.4                       PSI
  11.7            635    PSI                          14.4                       PSI
  11.8            612    PSI                          14.4                       PSI
  11.9            588    PSI                          14.4                       PSI
  12.0            565    PSI                          14.4                       PSI
  12.1            542    PSI                          14.4                       PSI
  12.2            518    PSI                          14.4                       PSI
  12.3            495    PSI                          14.4                       PSI
  12.4            471    PSI                          14.4                       PSI
  12.5            448    PSI                          14.4                       PSI

				
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