Version 2002.1 Released January 2002

WELL CONTROL TOOLKIT

2. Pressure Loss Calculator

Common Data Input

1. Kick Tolerance Calculator

4. Kill Sheet - Subsea BOPs 3. Kill Sheet - Surface BOPs

5. Volumetric Control Sheets 6. Casing Pressure Profile

Unit Converter

For more information . . .

User Guide

QuitExcel

Quit Toolkit

2002

2. Pressure Loss Calculator

4. Kill Sheet - Subsea BOPs

6. Casing Pressure Profile

For more information . . .

User Guide

document.xls 04/20/2023 02:19:17

COMMON DATA INPUTVersion 2002.1 Released January 2002 Units (UK/US): UK

Well No: 9808 Date: 7 09 07 f

Rig Name: 249 Time: 1:09 PM Surface BOP Setup.

Casing / Hole Configuration Surface Drillstring Configuration

OD ID Depth Input Pipe OD ID Length

(inch) (inch) (m) ID (in): 3 (inch) (inch) (m)

Casing: 13.625 12.415 1430 Len (m): 150 Drillpipe 1: 5 4.8 4150

Liner 1: Choke Line Drillpipe 2:

Liner 2: ID (in): 3 HWDP: 7 4 50

Openhole Size (inch): 12.25 4400 Len (m): 100 DC: 8 2.8 200

Well Shut-in Data Drilling Mud Formation / Equipment Integrity

Shut-in Time (h:m): 9:30 AM Mud Weight (sg): 1.070 Openhole Weak Point MD (m): 2650

Bit MD (m): 4400 PV (cP): 30 Openhole Weak Point TVD (m): 2650

Bit TVD (m): 3190 YP (lbf/100sqft): 20 Min Leak-off /FIT EMW (sg): 1.120

Shut-in DP Pres (psi): 100 Surf Active Vol (bbl): 800 Max Leak-off /FIT EMW (sg): 1.180

Shut-in Csn Pres (psi): 100 Reserve Vol (bbl): 1000 Casing Burst Pressure (psi): 5000

Shut-in Pit Gain (bbl): 20 Baryte on Site (MT): 1000 Max Allowable Surf Pres (psi): 5000

Mud Pump Data SCR Data (mud return via flowline)

Liner Size Max Pres Vol Eff 100% Pump Pump 1: Pump 2:

(inch) (psi) % bbl/stk SPM bbl/min Pscr (psi) bbl/min Pscr (psi)

Pump 1: 5.5 5000 97 0.088 20 1.707 350 1.707 360

Pump 2: 5.5 5000 97 0.088 30 2.561 500 2.561 515

Pump 3: 5.5 5000 97 0.088 40 3.414 700 3.414 720

Formation Pressure / Temperature Bit Pressure Safety Factors:

Min Pore Pressure (sg): 1.03 Nozzles Surf Pres Safety Factor for Kick Toler (psi): 100

Max Pore Pressure (sg): 1.07 (inch^2) Minimum Bottom Hole Over-B During Kill (psi): 100

Surface Temperature (deg.F): 80 0.451 Operating Margin for Vol Control (psi): 100

Weak Point Temperature (deg.F): 120 Operating Margin for Lubrication (psi): 100

Kick Zone Temperature (deg.F): 180

Well Profile

MD (m) TVD (m) MD X Y

Surface: 0 0 0 0 0

Kick-Off 1: 0 0 0 0 0

End-Built 1: 0 0 0 0

DP Cross-Over: 0 0 0 0

Kick-off 2: 0 0 0 0

End-Built /Drop 2: 0 0 0 0

Bit: 4400 3190 4400 3030 3190

For Kick Tolerance only:

Angle below Weak Point (deg):

Angle at Bit Depth (deg):

Angle above Horizontal (deg):

Horizontal Section Length (m):

Surface BOPs: Keep Following Green Cells Blank !

0

0 0

SurFace or Subsea BOP Stack (F/S) ?

0 500 1000 1500 2000 2500 3000 35000

500

1000

1500

2000

2500

3000

3500

Horizontal Departure

Ve

rtic

al

De

pth

document.xls Page 4 of 2 04/20/2023 02:19:18

KICK TOLERANCE CALCULATORFor Vertical, Deviated or Horizontal Wells

Version 2002.1 Released January 2002

Well: 9808 Units (UK/US): us

Kick Zone Parameters: Input Error Messages:1 Openhole Size ? (inch) 8.5 2 Measured Depth ? (ft) 64053 Vertical Depth ? (ft) 64054 Horizontal Length (>87 deg) ? (ft) Non-Horizontal5 Tangent Angle Above Horizontal ? (deg)6 Min Pore Pressure Gradient ? (ppg) 10.0007 Max Pore Pressure Gradient ? (ppg) 10.0008 Kick Zone Temperature ? (deg.F) 100

Weak Point Parameters:9 Measured Depth ? (ft) 180010 Vertical Depth ? (ft) 180011 Section Angle (<87 deg) ? (deg)12 Min Fracture Gradient / EMW ? (ppg) 20.000 13 Max Fracture Gradient / EMW (ppg) 20.00014 Weak Point Temperature ? (deg.F) 100

Other Parameters:15 Drill Collar OD ? (inch) 6.2516 Drill Collar Length ? (ft) 20017 Drillpipe OD ? (inch) 5.518 Surface Pressure Safety Factor ? (psi) 0 At least 100 psi !19 Mud Weight in Hole ? (ppg) 9.500

Annular Capacity Around BHA: (bbl/ft) 0.03224Annular Capacity Around DP: (bbl/ft) 0.04080

At Min Fracture Gradient: Comments: Circulating MAASP (psi) 981Gas Gradient at Weak Point (psi/ft) #VALUE!For Min Pore Pressure:Max Allowable Gas Height: (ft) #VALUE! #VALUE!Kick Tolerance: (bbl) #VALUE!For Max Pore Pressure:Max Allowable Gas Height: (ft) #VALUE! #VALUE!Kick Tolerance: (bbl) #VALUE!

At Max Fracture Gradient:Circulating MAASP (psi) 981Gas Gradient at Weak Point (psi/ft) #VALUE!For Min Pore Pressure:Max Allowable Gas Height: (ft) #VALUE! #VALUE!Kick Tolerance: (bbl) #VALUE!For Max Pore Pressure:Max Allowable Gas Height: (ft) #VALUE! #VALUE!Kick Tolerance: (bbl) #VALUE!

Min Fracture GradMax Fracture Grad10.00 #VALUE! #VALUE!10.00 #VALUE! #VALUE!10.00 #VALUE! #VALUE!

APPENDIX: Maximum Allowable Gas Influx VolumeBased on Casing Burst & Surface Equipment Rating

Max Allowable Surface Pressure ? (psi) 5000Near Surface Casing ID ? (inch) 12.8Near Surface Annular Temperature ? (deg.F) 80Gas Gradient at Max Surface Pres: (psi/ft) #VALUE!Near Surface Annular Capacity: (bbl/ft) 0.12976At Minimum Pore Pressure Gradient: Comments:Max Allowable Gas Height at Surface: (ft) #VALUE! #VALUE!Max Allowable Gas Vol. on Shut-in: (bbl) #VALUE!At Maximum Pore Pressure Gradient:Max Allowable Gas Height at Surface: (ft) #VALUE! #VALUE!Max Allowable Gas Vol. on Shut-in: (bbl) #VALUE!

10.00 #VALUE!10.00 #VALUE!10.00 #VALUE!

8.00 10.00 12.00 14.00 16.00 18.00 20.000

2

4

6

8

10

12

Min Fracture Grad Max Fracture Grad

Pore Pressure Gradient

Kic

k T

ole

ran

ce

(b

bl)

8.00 10.00 12.00 14.00 16.00 18.00 20.000

2

4

6

8

10

12

Pore Pressure Gradient

Ma

x A

llow

ab

le G

as

Vo

lum

e (

bb

l)

document.xls 04/20/2023 02:19:18

PRESSURE LOSS CALCULATORVersion 2002.1 Released January 2002 UK

Units (UK/US): UK

Weight PV YP Mud SCR Range(sg) (cP) (lbf/100sqft) (bbl/min)

Original Mud: 1.100 30 20 Minimum: 1Kill Weight Mud: 1.120 30 20 Maximum: 5

CHOKE LINE DIMENSION:Length ID

(m) (inch)Section 1: 1000 3.5Section 2: 0 0

Choke Line Pressure Loss:

Mud SCR Pressure Loss (psi)(bbl/min) Original Mud Kill Mud

1 #VALUE! #VALUE!2 #VALUE! #VALUE!3 #VALUE! #VALUE!4 #VALUE! #VALUE!5 #VALUE! #VALUE!

ANNULUS DIMENSION:Length Casing ID String OD

(m) (inch) (inch)70.0 18.750 5.5250.0 17.500 5.5

Annulus Pressure Loss:Mud SCR Pressure Loss (psi)(bbl/min) Original Mud Kill Mud

1 #VALUE! #VALUE!2 #VALUE! #VALUE!3 #VALUE! #VALUE!4 #VALUE! #VALUE!5 #VALUE! #VALUE!

0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.50

2

4

6

8

10

12

Original Mud Kill Mud

Slow Circulation Rate (bbl/min)

Pre

ssure

Loss (

psi)

0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.50.0

2.0

4.0

6.0

8.0

10.0

12.0

Original Mud

Slow Circulation Rate (bbl/min)

Pre

ssur

e Lo

ss (p

si)

document.xls Page 6 of 3 04/20/2023 02:19:18

KILL SHEETFor Vertical / Deviated Wells with Surface BOPs

Version 2002.1 Released January 2002 Units (UK/US):

Well No: Test Case A1 Rig: Rig Name Date: 22-Jan-02 Time:

Hole Size (inch): 12.25 Casing OD (inch): 13.375 Shoe TVD (ft): 4000 Shoe MD(ft)

Openhole Weak Point: TVD (ft) 4000 MD (ft) 4000 Fracture Grad EMW (ppg):

Csn Burst (psi): 5020 Barite on Site (sack) 1000 Reserve Mud Vol (bbl):

Drill String Contents (From Surface to Bottom)

OD ID (bbl/ft) Len (ft) Depth (ft) Vol (bbl) Cumulative Volume (bbl)

DP Size 1: 5 4.276 0.01777 9100 9100 161.7

DP Size 2: 0.00000 0 0.0 161.7

Heavy Weight DP: 5 3 0.00875 600 9700 5.2 166.9

Drill Collar: 8 2.5 0.00607 300 10000 1.8 168.8

Annulus Contents (From Surface to Bottom)

Casing/Hole ID Strg OD Capacity (bbl/ft) Len (ft) Depth (ft) Vol (bbl) Cumulative Volume (bbl)

Casing: 12.415 5 0.12549 4000 4000.00 502.0

12.25 5 0.12154 5100 9100.00 619.8 1121.8

12.25 5 0.12154 600 9700.00 72.9 1194.7

12.25 8 0.08364 300 10000.00 25.1 1219.8

Surf Input Line: OD= ID= 3.00 in Length (ft): 150 Vol (bbl):

Choke Line: OD= ID= 3.00 in Length (ft): 100 Vol (bbl):

Total Circ System Vol (bbl): 1391 Surf Active (bbl): 800 Total Active Mud Vol (bbl):

Pumping Data

Pump 1 Liner (in): 5.5 Max Pres (psi): 5000 Vol Eff (%): 97 100% bbl/stk:

Pump 2 Liner (in): 5.5 Max Pres (psi): 5000 Vol Eff (%): 97 100% bbl/stk:

PUMP 1 PUMP 2 KILL CIRCULATION TIMES (min)

SPM bbl/min Pscr bbl/min Pscr Pump No Surface to Bit Bit to Shoe Shoe to Chk

20 1.707 350 1.707 360 1 98.9 420.5 294.0

30 2.561 500 2.561 515 65.9 280.3 196.0

40 3.414 700 3.414 720 49.4 210.2 147.0

Kick Data Near vertical well !

Time Shut-In: 9:30 AM Bit at TD (ft): 10000 TVD (ft): 10000

Mud Weight in Hole (ppg): 12.000 PV (cP): 30 YP (lbf/100ft^2):

SIDPP (psi): 400 Shut-in Casing Pres (psi): 600 Shut-in Pit Gain (bbl):

Kill MW (ppg), MW2= 12.769 Barite Required (lb/bbl): 50.4 Total (sack):

Pressure Losses

Kill Pump SPM: 30 Bit Circ Pressure Losses (psi): Annular Pressure Loss (APL) (psi):

bbl/stroke: 0.08536 Nozzles Surf Input Pipe: #VALUE! APL - Based on SCR Test:

Kill Rate (bbl/min) 2.561 (in^2) Inside Drill String: #VALUE! APL - Directly Calculated:

SCR Pres (psi): 500 0.451 Drill Bit: 63 #VALUE!

Conventional vertical / high angle kill

document.xls Page 7 of 3 04/20/2023 02:19:18

US

1:09 PM

4000

13.50

1000

Cumulative Volume (bbl)

Cumulative Volume (bbl)

1.3

0.9

2191

0.088

0.088

Total

813

542

407

20

30

1104.7

Annular Pressure Loss (APL) (psi):

#VALUE!

#VALUE!

document.xls Page 8 of 3 04/20/2023 02:19:18

Kill Data

Kill Start Time: Kill Mud to Reach: Drill Bit: Choke: MAASPs (psi):

Keep this cell blank: 100 Pump Strokes: 1977 16268 Static:

Initial Circ Pres (psi): 900 Pump Pres (psi): 532 532 Circulating:

Standpipe Pressure (For Pumping Down Kill Mud Through Drill String)

Section Point: MD (ft) TVD (ft) Vol (bbl) Strokes Time (min) Standpipe Pressure (psi)

From: Surface: 0 0 0.0 0 0 900

0 0.0 0 0.0

0.0 0 0.0

0 0.0 0 0.0

0.0 0 0.0

0.0 0 0.0

To: Drill Bit: 10000 10000 168.8 1977 65.9 532

STANDPIPE PRESSURE TABLEPump Pred. DP Actual DP Actual Choke Pump Pred. DP Actual DP

Stroke Pres Pressure Pressure Stroke Pressure Pressure

(psi) (psi) (psi) (psi) (psi)

0 1500 1 16 1760 1342 17

110 1486 2 15 1870 1336 18

220 1472 3 14 1980 1329 19

330 1458 4 13 2090 1323 20

440 1445 5 12 2200 1317 21

550 1435 6 11 2310 1310 22

660 1425 7 10 2420 1304 23

770 1415 8 9 2530 1298 24

880 1405 9 8 2640 1291 25

990 1395 10 7 2750 1285 26

1100 1385 11 6 2860 1279 27

1210 1375 12 5 2970 1272 28

1320 1368 13 4 3080 1266 29

1430 1361 14 3 3190 1260 30

1540 1355 15 2 3222 1258 31

1650 1348 16 1 Hereafter maintain DP pressure constant @

0 500 1000 1500 2000 25000

100

200

300

400

500

600

700

800

900

1000

Pump Strokes to Bit (Stroke)

Sta

nd

pip

e P

res

su

re (

ps

i)

STANDPIPE PRESSURE CHART

document.xls Page 9 of 3 04/20/2023 02:19:18

MAASPs (psi):

312

#VALUE!

Standpipe Pressure (psi)

( =Pic )

( =Pfc )

Actual Choke

Pressure

(psi)

31

30

29

28

27

26

25

24

23

22

21

20

19

18

17

1258 psi

0 500 1000 1500 2000 25000

100

200

300

400

500

600

700

800

900

1000

Pump Strokes to Bit (Stroke)

Sta

nd

pip

e P

res

su

re (

ps

i)

STANDPIPE PRESSURE CHART

document.xls Page 10 of 3 04/20/2023 02:19:18

GENERAL KILL PROCEDURE

Pump Start Up Procedure: Pump Choke

~ When the choke pressure gauge starts to respond in each step, Speed Pressure

manipulate the choke valve to adjust the choke pressure (SPM) (psi)

according to the table on the right. 0 600

~ Zero the stroke counter when kill mud has reached rig floor. 6 600

~ When the pump has reached the kill speed, record the initial 12 600

circulating pressure and compare with the calculated value. 18 600

~ If the recorded and calculated values are close to each other, 24 600

continue the kill operation. If they are significantly different, stop 30 600

the pump, shut-in the well and investigate.

If choke pressure in the above table is constant, the conventional kill method will be used, which will ignore

Annular Pressure Loss (APL) to provide an over-balance pressure.

If choke pressure is decreasing during pump start up, the slimhole technique will be used, which will compensate

APL during kill. When APL is relatively high however, it may be impossible to fully compensate APL. In this

case, the choke pressure will reduce to zero and the choke valve become wide-open during pump start up.

Displacing Drillpipe and Annulus with Kill Mud:

Once the pump has reached kill speed, the choke valve should be adjusted to control the DP pressure so that the

bottom hole pressure is maintained constant. This means that:

~ During the 1st complete circulation using Driller's method, the DP pressure be maintained constant at the

initial circulating pressure.

~ When kill weight mud is being pumped down the drillpipe (using either Driller's or W&W), the DP pressure

be adjusted according to the standpipe pressure chart & table shown in the 2nd page of the kill sheet.

Once the kill mud has entered into the annulus, the DP pressure should be maintained constant. However, at

some point when the annulus is being displaced by kill mud, or after the influx is out of hole, the choke valve

may become wide-open. From then on, DP pressure will increase gradually while choke valve is kept at

the full open position. This will continue until the kill mud reaches the choke, at which DP pressure should be

equal or close to the value shown in the "Kill Data" Section.

Complete Kill Operation:

~ When the kill mud has returned to surface, stop the pump and close the choke valve to check drillpipe and

choke pressures.

~ If both drillpipe and choke pressures are zeros, open the BOP and further flow-check the annulus.

~ A further complete circulation should be carried out. In the mean time, a suitable overbalance should be

added to the mud weight.

document.xls Page 11 of 3 04/20/2023 02:19:18

Drillpipe

Pressure

(psi)

400

500

600

700

800

900

document.xls Page 12 of 3 04/20/2023 02:19:18

KILL SHEETFor Vertical / Deviated Wells with Subsea BOPs

Version 2002.1 Released January 2002 Units (UK/US):

Well No: WFC Rig: Rig Name Date: 02.oct.2003 Time:

Hole Size (inch): 17.5 Casing OD (inch): 20 Shoe TVD (m) 2650 Shoe MD (m)

Openhole Weak Point: TVD (m) 2650 MD (m) 2650 Fracture Grad EMW (sg):

Csn Burst (psi): 5000 Baryte on Site (MT): 1000 Reserve Mud Vol (bbl):

Drill String Contents (From Surface to Bottom)

OD ID (bbl/m) Len (m) Depth (m) Vol (bbl) Cumulative Volume (bbl)

DP Size 1: 5.5 4.8 0.07342 3050 3050 223.9

DP Size 2: 0.00000 0 0.0 223.9

Heavy Weight DP: 7 4 0.05099 50 3100 2.5 226.5

Drill Collar: 8 2.8 0.02498 90 3190 2.2 228.7

Annulus Contents (From Surface to Bottom)

Casing/Hole ID Strg OD Capacity (bbl/m) Len (m) Depth (m) Vol (bbl) Cumulative Volume (bbl)

Riser: 18.75 5.5 1.02394 1990 1990.0 2037.6

Casing: 18.75 5.5 1.02394 660 2650.0 675.8 2713.4

17.5 5.5 0.87954 400 3050.0 351.8 3065.3

17.5 7 0.81979 50 3100.0 41.0 3106.2

17.5 8 0.77199 90 3190.0 69.5 3175.7

Surf Input Line: OD= ID= 3.00 in Length (m): 150 Vol (bbl):

Total Circ System Vol (bbl): 3409 Surf Active (bbl): 800 Total Active Mud Vol (bbl):

Subsea Choke / Kill Line Setup

Choke Line Kill Line Sea Water Depth (m) 2000 Air Gap (m)

Section ID (in) Len (m) ID (in) Len (m) Fluid in Choke Line: Density (sg):

Subsea: 1990 1990 Fluid in Kill Line: Density (sg):

Surface:

Pumping Data

Pump 1 Liner (in): 5.5 Max Pres (psi): 5000 Vol Eff (%): 97 100% bbl/stk:

Pump 2 Liner (in): 5.5 Max Pres (psi): 5000 Vol Eff (%): 97 100% bbl/stk:

SCR Tests (Return from Riser) Kill Using Pump No.: 1

PUMP 1 PUMP 2 KILL CIRCULATION TIMES (min)

SPM bbl/min Pscr bbl/min Pscr Total Surface to Bit Bit to Shoe Shoe to BOP

20 1.707 350 1.707 360 801 134.0 270.8 395.9

30 2.561 500 2.561 515 534 89.3 180.5 263.9

40 3.414 700 3.414 720 400 67.0 135.4 197.9

Kick Data Near vertical well !

Time Shut-In: 9:30 AM Bit at TD (m): 3190 TVD (m): 3190

Mud Weight in Hole (sg): 1.070 PV (cP): 30 YP (lbf/100ft^2):

SIDPP (psi): 100 Shut-in Casing Pres (psi): 100 Shut-in Pit Gain (bbl):

Kill MW (sg), MW2= 1.092 Barytes Required (lb/bbl): 10.4 Total (MT):

Pressure Losses

Kill Pump SPM: 30 Bit Circ Pressure Losses (psi): Annular Pressure Loss (APL) (psi):

bbl/stroke: 0.08536 Nozzles Surf Input Pipe: Err:508 APL - Based on SCR Test:

Kill Rate (bbl/min) 2.561 (in^2) Inside Drill String: Err:508 APL - Directly Calculated:

SCR Pres (psi): 500 0.451 Drill Bit: 47 User Accepted APL:

Calculated Choke Line Loss (CLL) (psi): Err:508

User Accepted CLL (psi): 0 SCR Pressure Through Choke (psi):

document.xls Page 13 of 3 04/20/2023 02:19:18

UK

1:09 PM

2650

1.15

1000

Cumulative Volume (bbl)

Cumulative Volume (bbl)

4.3

4209

-10

0.088

0.088

BOP to Chk

0.0

0.0

0.0

20

20

19.9

Annular Pressure Loss (APL) (psi):

Err:508

Err:508

500

document.xls Page 14 of 3 04/20/2023 02:19:18

Err:508

Kill Data

Kill Start Time: Kill Mud to Reach: Drill Bit: Choke: MAASPs (psi):

Keep this cell blank: 100 Pump Strokes: 2680 16012 Static:

Initial Circ Pres (psi): 600 Pump Pres (psi): 510 510 Circulating:

Standpipe Pressure (For Pumping Down Kill Mud Through Drill String)

Section Point: MD (m) TVD (m) Vol (bbl) Strokes Time (min) Standpipe Pressure (psi)

From: Surface: 0 0 0.0 0 0 600

2000 2000 146.8 1720 57.3 544

#VALUE! #VALUE! #VALUE!

0.0 0 0.0

#VALUE! #VALUE! #VALUE!

0.0 0 0.0

To: Drill Bit: 3190 3190 228.7 2680 89.3 510

STANDPIPE PRESSURE TABLEPump Pred. DP Actual DP Actual Choke Pump Pred. DP Actual DP

Stroke Pres Pressure Pressure Stroke Pressure Pressure

(psi) (psi) (psi) (psi) (psi) (psi) (psi)

0 600 1 21 1440 553 7

90 597 2 20 1530 550 3

180 594 3 19 1620 547 9

270 591 4 18 1710 544 0

360 588 5 17 1800 541 1

450 585 6 16 1890 538 2

540 582 7 15 1980 535 3

630 579 8 14 2070 532 4

720 576 9 13 2160 528 5

810 574 0 12 2250 525 6

900 571 1 11 2340 522 7

990 568 2 10 2430 519 8

1080 565 3 9 2520 516 9

1170 562 4 8 2610 513 0

1260 559 5 7 2680 510 1

1350 556 6 6 Hereafter maintain DP pressure constant @

0 500 1000 1500 2000 2500 3000 3500460

480

500

520

540

560

580

600

620

Pump Strokes to Bit (Stroke)

Sta

nd

pip

e P

ress

ure

(p

si)

STANDPIPE PRESSURE CHART

document.xls Page 15 of 3 04/20/2023 02:19:18

MAASPs (psi):

301

Err:508

Standpipe Pressure (psi)

( =Pic )

( =Pfc )

Actual Choke

Pressure

(psi)

5

4

3

2

1

0

9

8

7

6

5

4

3

2

1

510 psi

0 500 1000 1500 2000 2500 3000 3500460

480

500

520

540

560

580

600

620

Pump Strokes to Bit (Stroke)

Sta

nd

pip

e P

ress

ure

(p

si)

STANDPIPE PRESSURE CHART

document.xls Page 16 of 3 04/20/2023 02:19:18

GENERAL KILL PROCEDURE

Shut-in surface choke pressure is 100 (pis) with 0 in choke line.

Surface choke pressure will become -2926 (psi) when choke line is displaced to mud in hole.

Shut-in surface kill line pressure is: 100 (psi) with 0 in kill line.

Kill line pressure becomes 100 (psi) when displaced to with (sg) =

Pump Start Up Procedure: Pump Choke Kill Line

~ Start the pump and increase its speed in small steps. Speed Pressure Pressure

~ When choke pressure gauge starts to respond in each (SPM) (psi) (psi)

step, manipulate choke valve to adjust choke/kill line 0 -2926 100

pressure according to the table on the right. 6 -2926 100

~ Zero stroke counter when kill mud reaches rig floor. 12 -2926 100

~ When pump has reached kill speed, record the initial 18 -2926 100

circulating pressure and compare with calculated value. 24 -2926 100

~ If the recorded and calculated values are close to each 30 -2926 100

other, continue the kill operation. If they are significantly different, stop pump, shut-in the well and investigate.

If the choke pressure in above table is constant, the conventional kill method will be used, which will ignore both

Choke Line Loss (CLL) and Annular Pressure Loss (APL) to provide an over-balance pressure.

If the choke pressure is decreasing during pump start up, the deep water and/or slimhole techniques will be used,

which will compensate CLL and/or APL during kill. When the shut-in surface choke pressure is relatively low

however, it may be impossible to fully compensate CLL and/or APL. In this case, the choke pressure will reduce

to zero and the choke valve become wide-open during pump start up.

Displacing Drillpipe and Annulus with Kill Mud:

Once the pump has reached kill speed, the choke valve should be adjusted to control the drillpipe pressure so that

the bottom hole pressure is maintained constant. This means that:

~ During the 1st complete circulation using Driller's method, the drillpipe pressure be maintained constant at the

initial circulating pressure.

~ When kill weight mud is being pumped down the drillpipe (using either Driller's or W&W), the drillpipe pressure

be adjusted according to the standpipe pressure chart & table shown in the 2nd page of the kill sheet.

Once the kill mud has entered into the annulus, the drillpipe pressure should be maintained constant. However, at

some point when the annulus is being displaced by kill mud, or after the influx is out of hole, the choke valve

may become wide-open. From then on, drillpipe pressure will increase gradually while choke valve is kept at the

full open position. This will continue until the kill mud reaches the choke, at which drillpipe pressure should be equal

or close to the value shown in the "Kill Data" Section.

Complete Kill Operation:

~ When the kill mud has returned to surface, stop the pump and close the choke valve to check the drillpipe and

choke pressures.

~ If both drillpipe and choke pressures are zeros, start to implement procedures for removing the gas possibly

trapped in BOP stack. Then displace the riser annulus to kill mud.

~ Open the BOP and further flow-check the annulus.

~ A further complete circulation should be carried out. In the mean time, a suitable overbalance should be added

to the mud weight.

document.xls Page 17 of 3 04/20/2023 02:19:18

Drillpipe

Pressure

(psi)

100

200

300

400

500

600

document.xls Page 18 of 2 04/20/2023 02:19:18

VOLUMETRIC CONTROL SHEETFor Controlling Gas Expansion During Well Shut-in

Version 2002.1 Released January 2002 Units (UK/US):Well No: Test Case A1 Rig: Rig Name Date: 22-Jan-02 Time Well Shut-in:

Open Hole Size (inch): 12.25 TD (ft): 10000 TVD (ft): 10000

Open Hole Weak Point: TD (ft): 4000 TVD (ft): 4000 Frac Gradient (ppg):

Shut-in DP Pres (psi): 500 Shut-in Csn Pres (psi): 750 MW in Hole (ppg):

Bottom Hole Pres on Shut-in (psi): 6734 = Pres Gradient (ppg): 12.962 Shut-in Pit Gain (bbl)

Weak Point Pressure on Shut-in (psi): 3244 = Pres Gradient (ppg): 15.609 20

Upper or Average Annular Capacity (bbl/ft): 0.12549 Annular Mud Hydrostatic (psi/bbl)

O-B Safety Factor (psi): 100 Operating Margin (psi): 100 = Equi Mud Vol (bbl):

Can drillpipe pressure gauge be used to monitor bottom hole pressure (Y/N) ?

Volumetric Control LogFor Controlling Gas Expansion Before Reaching BOP Stack

Drillpipe Change in Mud Bled Hydrostatic Total Mud

Time Operation Pressure DP Pres at Choke Loss Bled

(hr:min) (psi) (+/- psi) (bbl) (psi) (bbl)

Shut-in Condition 500 ~ ~ ~ ~

Add Over-B Safety Facotr: 600 100 ~ ~ ~

Add operating margin 700 100 ~ ~ ~

Bleed DP pres back to: 600 -100 0

Add operating margin 0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

0 ~ ~ ~

0

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LUBRICATION LOGFor Venting Gas From Beneath BOP Stack

Version 2002.1 Released January 2002

Upper Annulus Casing ID (inch) : 12.415 String OD: 5 Annular Cap (bbl/ft):

Lubricating MW (ppg) : 12 Hydrostatic (psi/bbl): 4.97 Operating Margin (psi):

Choke Change in Mud Vol Mud Vol Total Mud

Time Operation Pressure Choke Pres Pumped in Bled out Pumped in

(hr:min) (psi) (+/- psi) (bbl) (bbl) (bbl)

Before lubrication start ~ ~ ~ ~

~ ~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

~ ~

~

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US1:09 PM

13

12

Shut-in Pit Gain (bbl)

20

4.97

20.13

y

Over-B

Pressure

(psi)

0

100

200

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0.12549

100

Hydrostatic

Gain /Loss

(+/-psi)

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

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CASING PRESSURE PROFILEDuring Circulating out a Gas Influx

Version 2002.1 Released January 2002 Units (UK/US): UK

Mud Weight in Hole (sg) 1.07 Openhole Weak Point MD (m) 2650Shut-in Gas Influx Vol (bbl) 20 TVD (m) 2650

Shut-in Drillpipe Pressure (psi) 100 Surface Temp (deg.F): 80B'hole Over-Balance (psi) 100 Bottom Hole Temp (deg.F): 180

Formation Pore Pressure (psi) 4950 Temp Gradient (deg.F/m) 0.0313

Annular Hole/Csg String Section Bottom Section Section Total Annular

Section ID OD TD TVD Length Volume Volume Capacity

No. (inch) (inch) (m) (m) (m) bbl (bbl) (bbl/m)Surface: 18.750 5.500 0 0 ~ ~ ~ ~

1 18.750 5.500 1990.0 1990.0 1990.0 2037.6 3175.7 1.023942 18.750 5.500 2650.0 2650.0 660.0 675.8 1138.1 1.023943 17.500 5.500 3050.0 3050.0 400.0 351.8 462.3 0.879544 17.500 7.000 3100.0 3100.0 50.0 41.0 110.5 0.819795 17.500 8.000 3190.0 3190.0 90.0 69.5 69.5 0.77199

Weighted Average Annular Capacity (bbl/m): 0.99553

Max Pit Gain Volume (bbl) = #VALUE! Max Surf Casing Pres (psi) = #VALUE!Max Weak Point Pres (psi) = #VALUE! Max Weak Point EMW (sg) = #VALUE!

Surface Casing & Weak Point Pressure Profiles

0 500 1000 1500 2000 2500 3000 3500 40000

2

4

6

8

10

12

0

20

40

60

80

100

120

Weak Point PressureSurface Casing Pressure

Mud Volume Pumped (bbl)

We

ak

Po

int

Pre

ss

ure

(p

si)

Surf

ace C

asin

g P

ressure

(p

si)

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UNIT CONVERTERVersion 2002.1 Released January 2002

Conversion To SI Units Conversion To Customary Units

Length Length1 inch = 25.4 mm 100 mm = 3.9370081 ft = 0.3048 m 1 m = 3.280841 mile = 1.60934 km 1 km = 0.621373

Weight Weight1 lbf = 0.453592 kg 1 kg = 2.2046241 MT = 1000 kg 1000 kg = 1

Volume Volume1 US gal = 3.78541 litre 1 litre = 0.2641721 bbl = 158.987 litre 619 litre = 3.89341 ft^3 = 28.3168 litre 1 litre = 0.035315

Velocity Velocity100 ft/min = 0.508 m/s 1 m/s = 196.8504100 ft/min = 30.48 m/min 1 m/min = 3.28084

Volumetric Flow Rate Volumetric Flow Rate100 gal/min = 6.30902 L/s 1 L/s = 15.85032

1 bbl/min = 2.64978 L/s 1 L/s = 0.377391 MMscf/day = 327.774 L/s 100 bbl/min = 0.808498

Pressure Pressure100 psi = 6.89476 bar 1 bar = 14.50377100 psi = 689.476 kPa 29.9 kPa = 4.336627100 psi = 7.0307 kgf/cm^2 1 kgf/cm^2 = 14.22333

Pressure Gradient Pressure Gradient1 psi/ft = 22.6206 kPa/m 100 kPa/m = 4.420749

0.7 psi/ft = 1.613045 sg 1 sg = 0.43396210 ppg = 0.52

Density Density1 lbm/US gal = 119.826 kg/m^3 1000 kg/m^3 = 8.3454341 lbm/US gal = 0.119826 g/cm^3 1 g/cm^3 = 8.3454341 lbm/ft^3 = 0.016019 g/cm^3 1 g/cm^3 = 62.42782

1 ppg = 7.48052Concentration Concentration

1 lbm/bbl = 2.85301 kg/m^3 1 kg/m^3 = 0.3505071 lbm/bbl = 2.85301 g/L 1 g/L = 0.350507

Temperature Temperature100 deg.F = 37.27778 deg.C 165 deg.C = 329.9

Temperature Gradient Temperature Gradient1 deg.F/ft = 1.822689 deg.C/m 1 deg.C/m = 0.54864

* Conversion factors are based on "The SI Metric System of Units and SPE Metric Standard", API, June 1984

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Conversion To Customary Units

inchft

mile

lbMT

US galbblft^3

ft/minft/min

gal/minbbl/min

MMscf/day

psipsipsi

psi/ftpsi/ftpsi/ft

lbm/US gallbm/US gal

lb/ft^3lb/ft^3

lbm/bbllbm/bbl

deg.F

deg.F/ft* Conversion factors are based on "The SI Metric System of Units and SPE Metric Standard", API, June 1984

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WELL CONTROL TOOLKIT 2002

Version 2002.1 Released January 2002

Well Control Toolkit 2000 is a collection of Excel worksheets designed for drilling engineers and rig-sitepersonnel to record data and perform calculations related to well control.

Hardware & software requirement:A PC running under the BP Common Operating Environment (COE3) with Excel 2000.

To run Toolkit:~ To open Toolkit: Same way as you would do with an Excel file.~ When you first open Toolkit, the Main Menu will appear on the screen.~ Click on a button in Main Menu to open a worksheet.~ Upon finishing a worksheet, click on "Return to Menu" button in the worksheet.

All the worksheets have the following common features:

added to the Common Data Input Sheet, however UK and US units cannot be mixed.2. Easy to use: Just open a worksheet and input data into green cells, the results will be updated automatically.3. Data input is flexible: It can be done either in each of the worksheets directly, or imported from "Common Data Input" sheet, or imported from a saved data file.4. Some input cells have help-notes describing the input requirement. These cells have red triangle on their top-right hand corners. Position and keep the prompt on the cell, the help-notes should appear.5. Critical inputs are automatically checked. If found unreasonable, error messages will appear.6. Results are presented in both tabulated data and plots.7. All data and plots are laid out such that they can be easily printed on letter-sized papers.8. All plots are re-scaled automatically to fit input /output data range.

Common Data Input

"Common Data Input" (CDI) sheet is designed for entering well data, which can be then imported toother worksheets. Use of this sheet to input data has following advantages:1. It provides a single data input sheet for all other worksheets in Toolkit. So once this is filled in, it takes only seconds to get results on kick tolerance, kill sheet, or casing pressure profiles, etc.2. CDI sheet can be saved or imported separately from the Toolkit (top of sheet). 3. It is easier to input data into CDI. For example, there is no need to mentally work out how many annular sizes based on casing and drillstring data. This will be done automatically when importing data into kill sheets or casing annular pressure profile.4. It allows visual checks on well profiles once MD/TVD data have been inputted at kick-off, end-build, etc.5. The ability to convert units has been added, however UK and US units cannot be mixed.6. The ability to save data from all the sheets (workbook) has been added (right side). This feature will save or reimport data directly to the worksheets (includes data not included in the CDI).

1. KICK TOLERANCE CALCULATOR

1. User can choose to use either UK (m, sg) or US (ft, ppg) units. The ability to convert units has been

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Kick Tolerance Calculator (KTC) is designed to determine kick tolerance volumes, given well geometrydrilling parameters and hole condition. It can be used for vertical, deviated or horizontal wells.

The principles used in KTC are similar with those described in BP Well Control Manuals (Volume 1).However, KTC includes the effects of bottom hole pressure / temperature on gas density (for methanegas based on Hall & Yarborough's Equation of State). So it is more accurate, usually less conservative.It can cope with many scenarios (e.g. shut-in influx length is longer or shorter than BHA, etc.).

Kick tolerance is defined as the maximum volume of kick influx that can be shut-in andcirculated out without breaking down the weak point formation.Therefore, kick tolerance volume is determined based on two critical conditions:~ When the influx is at the hole bottom under the initial shut-in condition.~ When the influx top is displaced to the openhole weak point with the original mud weight.

It should be pointed out that, the pressure losses through annulus / choke lines and the possible chokeerror are considered by assuming a Surface Pressure Safety Factor. Therefore, this surface pressuresafety factor should be the sum of: 1. A choke operator error margin (say 100 psi) 2. Pressure loss through the choke line. For subsea BOPs, if the choke line pressure loss is to be compensated during kill by using the kill sheet in this Toolkit, then it can be totally or partially ignored. 3) Pressure loss through the annulus above the openhole weak point. In HPHT & ERD wells where there is a long casing & liner section, its annular pressure loss (APL) can be high. If it is included in the pressure safety factor, kick tolerance volume will be significantly reduced. In this case, APL should be compensated during kill by using the Kill Sheets in this Toolkit. In the mean time, APL can be totally or partially ignored in kick tolerance calculations.

In some cases, the calculated volume extends from bottom hole to above the casing shoe, which impliesthat the well can tolerate an unlimited volume of kick without breaking down the weak point formation.This often occurs when the vertical height of the openhole section is relatively short. If this occurs in ahigh angle or horizontal hole section where potential kick volume can be high, it is important to check the maximum allowable gas volume based on the casing burst strength and pressure ratings of BOPstack & choke manifold. This can be done in the 2nd page of the calculator.

2. PRESSURE LOSS CALCULATOR

Pressure Loss Calculator is designed to calculate pressure losses through choke lines and openhole/ casing annuli. The methods are based on the simple models as described in "Applied DrillingEngineering", SPE Textbook, 1986. The calculator can be used for:

~ Estimating the pressure safety factor in Kick Tolerance Calculator. This has been described in the previous section.

~ Estimating the over-pressure during a conventional kill operation. If a conventional method is used in a kill operation, the pressure loss through annulus is ignored to provide an over-pressure at the kick zone to prevent further influx from coming into the wellbore. This calculator can be used to estimate the magnitude of this over-pressure.

~ Estimating the annular pressure loss in small hole drilling. When hole size is relatively small (e.g. < 6"), the annular pressure loss may be high. If ignored as in a conventional kill method, the high annular pressure loss may cause formation breaking down. In this case, the special well control technique should be used, which will compensate the annular pressure loss. The kill sheets as described in the following will facilitate the implementation of the technique.

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3. KILL SHEET For Vertical / Deviated Wells With Surface BOPs

The Kill Sheet is designed to record data during drilling operations and to perform kill calculations whena well has been shut-in on a kick.

This kill sheet can be used for:~ Land or offshore rigs with surface BOPs.~ Vertical, deviated or horizontal wells (Straight, L- or S-shaped holes).~ Conventional or small hole sizes~ Single- or dual-sized drillpipe strings (plus HWDPs and DCs).~ Gas, oil or water kicks.

Kill TechniquesThis kill sheet incorporates both the conventional kill techniques (Drillers or W&W), where annularpressure loss (APL) is ignored, and the special kill technique where APL will be compensated. Theadvantage of the special kill technique is that it will result in lower wellbore pressures during kill , thusminimising the risk of formation breakdown at the weak point. This is particularly important in ERD,HPHT or small hole wells where APL can be high due to long / small casing annulus.

Before deciding on which kill technique to use, APL is calculated using two alternative methods:~ Based on SCR test data, where APL is obtained by subtracting the string and bit losses from the SCR pump pressure. This method is often more accurate when APL is relatively high (e.g. in small holes).~ Direct calculation, where APL is calculated based on annular sizes and mud properties. This is often more accurate when APL is relatively low (e.g. in conventional hole sizes).

Based on the above APL values, user can input an "Accepted APL" in the "Pressure Losses" section.A suitable kill technique will then be selected:~ If APL <= 150 psi, the conventional technique will be used where APL is ignored; You can choose to ignore APL in any case by keeping the "Accepted APL" cell blank.~ If APL > 150 psi and SICP is sufficiently high, then the special kill technique will be used to compensate APL during kill. User will be required to select an over-balance safety factor in the "Kill Data" section.~ If APL > 150 psi but SICP is low, then APL can only be partially compensated.The actual kill technique to be used will be displayed below the "Pressure Losses" section.

Kill Procedures:At the end of the kill sheet (page 3), some guidance is also given on kill procedures and how to use thekill sheet, etc.

4. KILL SHEET For Vertical / Deviated Wells With Subsea BOPs

This kill sheet is designed for deep water drilling with subsea BOPs. It can be used to record dataduring drilling operations, and to perform kill calculations.

The kick sheet is designed for:~ Offshore floating rigs where there are long choke /kill lines from the subsea BOP to rig floor.~ Vertical, deviated or horizontal wells (Straight, L- or S-shaped holes).~ Conventional or small hole sizes~ Single- or dual-sized drillpipe strings (plus HWDPs and DCs).~ Gas, oil or water kicks.

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The major difference between kill calculations for surface and subsea BOPs is in the choke lineloss (CLL). On a land or an offshore fixed rig with surface BOPs, CLL is usually low at kill pump ratesand can be ignored during kill operations. On a floating rig with subsea BOPs however, CLL can besignificantly higher. If ignored, it can result in excessive pressures in the wellbore and the consequenceof formation breaking down at the open hole weak point. The deep water kill technique should be usedin this case to compensate the CLL.

In this kill sheet, CLL is first calculated. Based on the calculated value and perhaps other rig-site tests,user can then input an accepted CLL for compensation during kill. This is done in the "Pressure Losses"section of the kill sheet. The Annular pressure loss (APL) can also be compensated if it is high. Thisis done in a similar way as in the previous kill sheet for Surface BOPs.

Kill Techniques:Once user has defined the accepted choke line loss (CLL) and annular pressure loss (APL) in "PressureLosses" section, a suitable kill technique will be selected:A. If CLL <=100psi and APL <= 100psi, both CLL and APL will be ignored. In this case, the conventional vertical / high angle kill technique will be used. You can choose to ignore both APL and CLL in any case by keeping the "Accepted APL" and "Accepted CLL" cells blank.B. If CLL > 100psi but APL <= 100psi, the deep water kill technique will be used to compensate CLL and APL will be ignored. When SICP is low (after choke line has been displaced to mud), however, CLL may be only partially compensated.C. If CLL <= 100psi but APL > 100 psi, the slimhole kill technique will be used to compensate APL and CLL will be ignored. When SICP is low (after choke line has been displaced to mud), however, APL may be only partially compensated.D. If CLL > 100 psi and APL > 100psi, the combination of deep water and slimhole kill techniques will be used to compensate both CLL and APL. User will be required to select an over-balance safety factor in the "Kill Data" section. If SICP is low (after choke line has been displaced to mud), however, CLL and APL will be only partially compensated.The actual kill technique to be used will be displayed above the "Kill Data" section.

Kill Procedures:At the end of the kill sheet (page 3), some guidance is also given on kill procedures and how to use thekill sheet, etc.

5. VOLUMETRIC CONTROL SHEETS

The volumetric control techniques are used during well shut-in period to control gas expansion due tomigration. The purposes of the techniques are to:1) Maintain the bottom hole pressure above the formation pressure to prevent further influx, and2) Control the bottom hole pressure below a preset limit to prevent formation breakdown.

For swabbed kicks, the techniques can be used as the final kill. For under-balanced kicks, however,the techniques only provide a temporary measure to control the wellbore pressure. The final kill can only be achieved by circulating kill mud into the hole. Therefore the techniques are only used whencirculating kill is impossible due to pumps breakdown, string washout, plugged bit nozzles or stringoff-bottom, etc. Also it is worthwhile to mention that volumetric control of an influx is only necessarywhen the influx contains free-gas which is migrating up the annulus.

Three techniques are included in the Toolkit:1) Volumetric control using drillpipe pressure gauge This is a relatively simple and accurate technique to control gas expansion. It should be used when there is communication between drillpipe pressure gauge and the wellbore annulus.

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2) Volumetric control using choke pressure gauge This technique is a less reliable technique for controlling gas expansion. So it is only used when use of DP pressure is impossible due to string washout, plugged nozzles or string off-bottom, etc.3) Static Lubrication The technique is used to vent gas from beneath BOP stack (both surface and subsea).

For more detailed information about the volumetric control techniques, please refer to:BP Well Control Manuals, Vol.I, Chapter 6, Section 2.

6. CASING PRESSURE PROFILES

This spreadsheet program is designed to calculate the casing pressure profiles at the casing shoeand surface when displacing a given volume of gas influx to surface. The calculations are based onthe following assumptions:1) The influx is free gas. For mixed influxes (gas/oil/water), only the gas component is considered. 2) The influx is a single gas bubble. Calculations based on this assumption usually give higher pressures and thus, it is conservative. 3) The mud displacing the influx has the original mud weight (Driller's method). If kill mud weight was used (Wait & Weight method), the casing shoe and surface pressures may be lower. Therefore, the pressure predictions from this program will be conservative.

UNIT CONVERTER

All the worksheets in this Toolkit have been designed for both the UK (m.sg) and US (ft.ppg) oilindustry units. This should cover most of the world-wide operations within BP. However, if you findany units used in your local operations are different from those in the worksheets, then this unitConverter can be used to convert your local units into either the UK or US units.

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Version 2002.1 Released January 2002

FOR USE WITH EXCEL 2000

DISCLAIMERThis Toolkit has been developed by BP Exploration Operating Company Limited ("BP") for internal use only. The calculations are based on the latest well control techniques and procedures. Every effort has

been made to ensure their correctness as well as their field applicability. However, BP makes no warranty of any kind, express or implied, with respect to this Toolkit including, but not limited to, the implied

warranties of mechantability and fitness for any purpose. BP shall have no liability for any loss or damage, however caused and of whatever nature, arising directly or indirectly from the use of this Toolkit.

No tool, however powerful and accurate, can ever replace sound professional judgement in the field to ensure that safe and sound techniques and procedures are followed in a well control

event.

Original Author - Yuejin Luo

For more information or help, please contact: Jonny Gent, E-mail: gentjl@bp.com Alan Billard, E-mail: billarda@bp.com