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Drilling - English API Formula Sheet
Section 1.
Filled-in Kill Sheet Exercises - Gauge Problem Actions.
Gauge Problem Exercises are constructed from a completed kill sheet ‘filled-in’ with all relevant volume and pressure calculations. Each question is based on the strokes, pump rate, drill pipe and casing gauge readings at a specific point in time during a well kill operation. Any one or a combination of these readings could indicate the action required. Options are shown in the multiple-choice answers. The casing and/or drill pipe pressures will only be relevant to the action if – • •
The casing and/or drill pipe pressures given in the question are below the expected pressures, or The casing and/or drill pipe pressures given in the question are 70 psi or more above the expected pressures.
Section 2.
Calculation Formula. Abbreviations used in this document bbl bbl/ft bbl/min bbl/stroke BHP BOP ft ft/hr ft/min lb/bbl LOT MAASP ppg psi psi/ft psi/hr SICP SIDPP SPM TVD 0.052
= = = = = = = = = = = = = = = = = = = = =
Barrels (US) Barrels (US) per foot Barrels (US) per minute Barrels (US) per stroke Bottom Hole Pressure Blowout Preventer Feet Feet per hour Feet per minute Pounds per barrel Leak-off Test Maximum Allowable Annular Surface Pressure Pounds per gallon Pounds per square inch Pounds per square inch per foot Pounds per square inch per hour Shut in Casing Pressure Shut in Drill Pipe Pressure Strokes per minute True Vertical Depth Constant factor
1. HYDROSTATIC PRESSURE (psi) Mud Density (ppg) x 0.052 x TVD (ft) 2. PRESSURE GRADIENT (psi/ft) Mud Density (ppg) x 0.052
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Drilling - English API Formula Sheet 3. DRILLING MUD DENSITY (ppg) Pressure (psi) ÷ TVD (ft) ÷ 0.052 or Pressure (psi) TVD (ft) x 0.052
7. EQUIVALENT CIRCULATING DENSITY (ppg) [Annular Pressure Loss (psi) ÷ TVD (ft) ÷ 0.052] + Mud Density (ppg) Or Annular Pressure Loss (psi) TVD (ft) × 0.052
+ Mud Density (ppg)
8. MUD DENSITY WITH TRIP MARGIN INCLUDED (ppg) [Safety Margin (psi) ÷TVD (ft) ÷ 0.052] + Mud Density (ppg) Or Safety Margin (psi) + TVD (ft) × 0.052
Mud Density (ppg)
9. NEW PUMP PRESSURE (psi) WITH NEW PUMP RATE approximate New Pump Rate (SPM) 2 � Old Pump Rate (SPM)
Old Pump Pressure (psi) × �
10. NEW PUMP PRESSURE (psi) WITH NEW MUD DENSITY approximate Old Pump Pressure (psi)×
New Mud Density (ppg) Old Mud Density (ppg)
11. MAXIMUM ALLOWABLE MUD DENSITY (ppg) [Surface LOT pressure (psi) ÷ Shoe TVD (ft) ÷ 0.052] + LOT Mud Density (ppg) or Surface LOT Pressure (psi) + Shoe TVD (ft )× 0.052
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Drilling - English API Formula Sheet 12. MAASP (psi) [Maximum Allowable Mud Density (ppg) – Current Mud Density (ppg)] x 0.052 x Shoe TVD (ft) 13. KILL MUD DENSITY (ppg) [SIDPP (psi) ÷ TVD (ft) ÷ 0.052] + Original Mud Density (ppg) or SIDPP (psi) + TVD (ft )× 0.052
Original Mud Density (ppg)
14. INITIAL CIRCULATING PRESSURE (psi) Kill Rate Circulating Pressure (psi) + SIDPP (psi) 15. FINAL CIRCULATING PRESSURE (psi) Kill Mud Density (ppg) Original Mud Density (ppg)
× Kill Rate Circulating Pressure (psi)
16. BARYTE REQUIRED TO INCREASE DRILLING MUD DENSITY (lb/bbl) [Kill Mud Density (ppg) - Original Mud Density (ppg)] × 1500 35.8 - Kill Mud Density (ppg)
17. GAS MIGRATION RATE (ft/hr) Rate of Increase in Surface Pressure (psi/hr) ÷ Drilling Mud Density (ppg) ÷ 0.052 or Rate of Increase in Surface Pressure (psi/hr) Drilling Mud Density (ppg) × 0.052
18. GAS LAWS
P1 x V1 = P2 x V2
P2 =
P1 × V1 V2
V2 =
P1 × V1 P2
19. PRESSURE DROP PER FOOT TRIPPING DRY PIPE (psi/ft) Drilling Mud Density (ppg) × 0.052 × Metal Displacement (bbl/ft) Riser or Casing Capacity (bbl/ft) - Metal Displacement (bbl/ft)
20. PRESSURE DROP PER FOOT TRIPPING WET PIPE (psi/ft) Drilling Mud Density (ppg) × 0.052 × Closed End Displacement (bbl/ft) Riser or Casing Capacity (bbl/ft) - Closed End Displacement (bbl/ft)
21. LEVEL DROP PULLING REMAINING COLLARS OUT OF HOLE DRY (ft) Length of Collars (ft) × Metal Displacement (bbl/ft) Riser or Casing Capacity (bbl/ft)
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Drilling - English API Formula Sheet
22. LEVEL DROP PULLING REMAINING COLLARS OUT OF HOLE WET (ft) Length of Collars (ft) × Closed End Displacement (bbl/ft) Riser or Casing Capacity (bbl/ft)
23. LENGTH OF TUBULARS TO PULL DRY BEFORE OVERBALANCE IS LOST (ft) Overbalance (psi) × [Riser or Casing Capacity (bbl/ft) - Metal Displacement (bbl/ft)] Mud Gradient (psi/ft) × Metal Displacement (bbl/ft)
24. LENGTH OF TUBULARS TO PULL WET BEFORE OVERBALANCE IS LOST (ft) Overbalance (psi)× [Riser or Casing Capacity (bbl/ft)- Closed End Displacement (bbl/ft)] Mud Gradient (psi/ft) × Closed End Displacement (bbl/ft)
25. VOLUME TO BLEED OFF TO RESTORE BHP TO FORMATION PRESSURE (bbl) Increase in Surface Pressure (psi) × Influx Volume (bbl) Formation Pressure (psi) - Increase in Surface Pressure (psi)
26. SLUG VOLUME (bbl) FOR A GIVEN LENGTH OF DRY PIPE Length of Dry Pipe (ft ) × Pipe Capacity (bbl/ft) × Drilling Mud Density (ppg) Slug Density (ppg) - Drilling Mud Density (ppg)
27. PIT GAIN DUE TO SLUG U-TUBING (bbl) Slug Volume (bbl) × �
28. RISER MARGIN (ppg)
Slug Density (ppg) − Drilling Mud Density (ppg)
1�
[Air Gap (ft) + Water Depth (ft)] × Mud Density (ppg) − [Water Depth (ft) × Sea Water Density (ppg)] TVD (ft) − Air Gap (ft) − Water Depth (ft)
29. HYDROSTATIC PRESSURE LOSS IF CASING FLOAT FAILS (psi) Mud Density (ppg) × 0.052 × Casing Capacity (bbl/ft) × Unfilled Casing Height (ft) Casing Capacity (bbl/ft) + Annular Capacity (bbl/ft)
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