DWC P&P - D1 - PPT - LEVEL 2
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This document outlines the schedule and details of a well control training course. The course will run from 8:00 AM to 5:00 PM daily, with a lunch break at 12:00 PM. It includes qualification exams that must be passed with a minimum 70% score to receive certification, which is valid for 5 years. The document also provides examples to calculate mud hydrostatic pressure and pressure gradients at various well depths and mud weights. Key well control concepts like primary and secondary barriers are defined. Causes of kicks like reductions in mud hydrostatic pressure from drops in mud level or weight are explained.
DWC P&P - D1 - PPT - LEVEL 2
- 1. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 1 WELL CONTROL
- 2. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 2 ■Emergency Exits & Muster Area: See Building Signs And Out Of Door, Down Stairs To The Assembly Point No-Smoking in the Building ■Start Time: 08: 00 AM ■Lunch Time:12 : 00 PM ■End Time: 05: 00 PM Sign-in Attendance Sheet Each Morning COURSE DETAILS
- 3. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 3 Qualification Exams ■Equipment Written Exam Time ■Surface Level 2 1 HR 10 minutes ■Combined Surface & Subsea Level 2 1 HR 10 minutes ■P&P Written Exam Time ■Surface Level 2 1 HR 45 minutes ■Combined Surface & Subsea Level 2 1 hrs 45 minutes 70% is the minimum required score to pass in each exam. ID or Passport is Required for Written. Certification Lasts 5 Years. IWCF CERTIFICATION
- 4. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 4
- 5. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 5 HYDROSTATIC PRESSURE Hydro- means a fluid Static- means at rest Hydrostatic in the wellbore is from the mud
- 6. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 6 EFFECT OF DENSITY 10 ppg 11 ppg 12 ppg PSI PSI PSI 5000’
- 7. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 7 EFFECT OF DEPTH 10 ppg 10 ppg 10 ppg PSI PSI PSI 5000’ 7500’ 10000’
- 8. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 8 MUD HYDROSTATIC -1 VERTECAL WELL STANDERED FORMULA WITH FT., PPG AND PSI MUD HYDROSTATIC HP = 0.052 X MUD WEIGHT X DEPTH MUD GRADIANT = 0.052 X MUD WEIGHT PSIFT.
- 9. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 9 Pressure (psi) = Mud Weight x .052 x TVD Pressure Gradient (psi/ft) = Mud Weight, ppg x .052 Pressure Gradient (psi/ft) =Pressure, psi TVD, ft Mud Weight, ppg = Pressure Gradient .052 Mud Weight (ppg) = Pressure TVD .052 TVD (ft) = Pressure (psi) Mud Weight (ppg) 0.052
- 10. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 10 TRY SOME EXAMPLES 1-Well TVD = 8000 ft. Calculate Mud Hydrostatic pressure for each of the following Mud Weights. 11 ppg 12 ppg 14 ppg 2-What Mud Weight is required to give a pressure gradient of 0.59 psi/ft? 3-Mud Hydrostatic = 3900 psi at the bottom of an 8000 ft. TVD well. What would be the pressure gradient for the mud? 4-For question above what is the equivalent Mud Weight (ppg)? 5-Pressure Gradient = 0.57 psi/ft. What is hydrostatic at 12000 ft. TVD?
- 11. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 11 1-Well TVD = 8000 ft. Calculate Mud Hydrostatic pressure for each of the following Mud Weights. 11 ppg 12 ppg 14 ppg 4576 psi 4992 psi 5824 psi TRY SOME EXAMPLES
- 12. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 12 1-Well TVD = 8000 ft. Calculate Mud Hydrostatic pressure for each of the following Mud Weights. 11 ppg 12 ppg 14 ppg 4576 psi 4992 psi 5824 psi 2-What Mud Weight is required to give a pressure gradient of 0.59 psi/ft? (11.4 ppg) TRY SOME EXAMPLES
- 13. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 13 1-Well TVD = 8000 ft. Calculate Mud Hydrostatic pressure for each of the following Mud Weights. 11 ppg 12 ppg 14 ppg 4576 psi 4992 psi 5824 psi 2-What Mud Weight is required to give a pressure gradient of 0.59 psi/ft? (11.4 ppg) 3-Mud Hydrostatic = 3900 psi at the bottom of an 8000 ft. TVD well. What would be the pressure gradient for the mud? ( 0.49 psift. ) TRY SOME EXAMPLES
- 14. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 14 1-Well TVD = 8000 ft. Calculate Mud Hydrostatic pressure for each of the following Mud Weights. 11 ppg 12 ppg 14 ppg 4576 psi 4992 psi 5824 psi 2-What Mud Weight is required to give a pressure gradient of 0.59 psi/ft? (11.4 ppg) 3-Mud Hydrostatic = 3900 psi at the bottom of an 8000 ft. TVD well. What would be the pressure gradient for the mud? ( 0.49 psift. ) 4-For question above what is the equivalent Mud Weight? ( 9.4 ppg ) TRY SOME EXAMPLES
- 15. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 15 1-Well TVD = 8000 ft. Calculate Mud Hydrostatic pressure for each of the following Mud Weights. 11 ppg 12 ppg 14 ppg 4576 psi 4992 psi 5824 psi 2-What Mud Weight is required to give a pressure gradient of 0.59 psi/ft? (11.4 ppg) 3-Mud Hydrostatic = 3900 psi at the bottom of an 8000 ft. TVD well. What would be the pressure gradient for the mud? ( 0.49 psift. ) 4-For question above what is the equivalent Mud Weight? ( 9.4 ppg ) 5-Pressure Gradient = 0.57 psi/ft. What is hydrostatic at 12000 ft. TVD? (6840 psi ) TRY SOME EXAMPLES
- 16. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 16 Formation Pressure: is the fluid pressure in the pore spaces of the formation. What is formation fluid pressure? PSI
- 17. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 17 • FORMATION FLUID GRADIANT IS GREATER THAN RESSURE GRADIANT OF SEA WATER. WHAT IS ABNORMAL PRESSURE? • 99.99+% OF FORMATION FLUIDS ARE WATER • FORMATION WATER EQUALS 8.9 PPG (AVERAGE) = .465 PSI/FT • IF FORMATION FLUIDS ARE SQUEEZED THEN FLUID PRESSURE INCREASES.
- 18. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 18 CAUSES OF ABNORMAL PRESSURE 1/ UNDER COMPACTION 2/ FAULTING 3/ SALT DOME 4/ ARTESIAN 5/ GAS CAP
- 19. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 19 Compaction = Dewatering Soft sediments Compacted Sedimentary Rock Increasing Depth and Compaction
- 20. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 20 Trapped Water in Clays Normal Pressure Abnormal Pressure Normal Pressure gradient Abnormal Pressure gradient
- 21. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 21 Sand Lens Normal Pressure Abnormal Pressure
- 22. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 22 FAULTING SAND A 0 0
- 23. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 23 FAULTING SAND A SAND A 0 0
- 24. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 24 SAND A SAND A FAULTING 0 0 0
- 25. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 25 SALT DOMES
- 26. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 26 0’ 500’ Spring Underground water level Rain 1000’ ARTESIAN EFFECTS
- 27. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 27 0’ 500’ Spring Underground water level Rain 1000’ ARTESIAN EFFECTS CALCULATE MUD WEIGHT TO BALANCE? FORMATION WATER = .433 PSI/FT
- 28. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 28 0’ 500’ Spring Underground water level Rain 1000’ ARTESIAN EFFECTS CALCULATE MUD WEIGHT TO BALANCE? FORMATION WATER = .433 PSI/FT
- 29. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 29 GAS CAP EFFECT 7000’ 8000’ .465 PSI/FT NORMAL PRESSURE
- 30. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 30 1/ PREVENTING A KICK PRIMARY MUD HYDROSTATIC OR 2/ SHUTTING IN THE WELL AFTER A KICK HAS BEEN TAKEN = SECONDARY BLOW OUT PREVENTERS WHAT IS WELL CONTROL?
- 31. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 31 Primary control PSI PSI FORMATION FLUID PRESSURE MUD HYDROSTATIC 5000 4800 MUD HYDROSTATIC IN WELLBORE MUD HYDROSTATIC PREVENTS FORMATION FLUIDS ENTERING THE WELLBORE
- 32. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 32 Secondary Control
- 33. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 33 Blowout Preventers
- 34. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 34
- 35. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 35 BARRIERS Primary Barrier Hydrostatic Barrier Secondary Barrier • Drilling fluid • Completion fluid • BOP Physical Barrier Operational Barrier Procedure Barrier • Fluids • BOP • Cement • Measuring Mwt. • Closing BOP. • Monitoring trip tank Temporary Barrier Permanent Barrier • Mud • BOP • Casing • Cement Closed Barrier Closable Barrier • Stuffing Box • Stripper Wire line Plug • BOP • Xmas Tree • Subsurface Safety Valve
- 36. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 36 CAUSES OF KICKS
- 37. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 37 HOW CAN KICKS HAPPEN? OR MUD HYDROSTATIC FORMATION PRESSURE RISES MUD HYDROSTATIC FALLS FORMATION PRESSURE
- 38. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 38 Mud Hydrostatic and Formation Pressure Always Remember that HP and FPare two opposite forces. FP HP
- 39. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 39 PRIMARY CONTROL ? GREATER / LESS ? = MUD HYDROSTATIC ? FORMATION PRESSURE NORMALLY:
- 40. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 40 PRIMARY CONTROL ? GREATER / LESS ? KICKS OCCUR WHEN: = MUD HYDROSTATIC ? FORMATION PRESSURE ? GREATER / LESS ? = MUD HYDROSTATIC ? FORMATION PRESSURE NORMALLY:
- 41. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 41 STAND RIG FLOOR FLOWLINE TOOL JOINT
- 42. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 42 RIG FLOOR FLOWLINE
- 43. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 43 RIG FLOOR FLOWLINE
- 44. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 44 RIG FLOOR FLOWLINE PULLING COLLARS
- 45. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 45 RIG FLOOR FLOWLINE PULLING COLLARS
- 46. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 46 RIG FLOOR FLOWLINE PULLING COLLARS
- 47. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 47 RIG FLOOR FLOWLINE FLOAT COLLAR CASING SHOE MUD LEVEL FAILURE OF FLOAT COLLAR
- 48. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 48 RIG FLOOR FLOWLINE FLOAT FAILS MUD LEVEL FAILURE OF FLOAT COLLAR
- 49. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 49 RIG FLOOR FLOWLINE MUD LEVEL FAILURE OF FLOAT COLLAR
- 50. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 50 CAUSES OF KICKS (REDUCTION IN MUD WEIGHT)
- 51. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 51 WHAT CAUSES MUD HYDROSTATIC TO DROP? PRESSURE = 0.052 X MUD WT X TVD
- 52. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 52 HOW CAN HYDROSTATIC PRESSURE CHANGE? Mud Level Mud Wt = 11 ppg Level Drop = 300 ft What is loss of hydrostatic pressure? { 300 ft Height (Length) True Vertical Rig Floor Mud Wt
- 53. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 53 ■ Adding water to the fluid system ■ - Use of centrifuges ■ - Gas-cut drilling fluid. Operations that can reduce hydrostatic head ■ Cement setting ■ Temperature effects on well bore fluids ■ Settling of weighting material ■ Swabbing. FACTORS THAT AFFECT FLUID DENSITY
- 54. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 54 ……..…......... ……..…......... ……... ……..…......... ……..…......... ……... Dry Wet Reduction In Hydrostatic Pressure Tripping Out Drill Collar Without Filling The Well
- 55. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 55 GAS IN THE WELLBORE • DRILLED GAS
- 56. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 56 0 Well depth 7000 feet Mud density 10.6 ppg Influx volume - gas 1/4 bbl Gas pressure at 7000’ P1 = 10.6 X .052 X 7000 = 3858 psi P1V1 = P2V2 3858 X ¼ = 14.7 X V2 Gas volume at surface = 65.6 bbl Gas Expansion Calculate gas volume at surface The greatest reduction in BHP when gas at surface. psi ……..…......... ……..…......... ……... Reduction In Hydrostatic Pressure Mud Pump
- 57. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 57 EFFECT OF GAS EXPANSION IN OPEN WELL 0 32 0 16 0 8 0 4 0 2 0 1
- 58. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 58 Gas In The Well Bore ■Drilled gas ■Gas cut mud ■Background gas Reduction In Hydrostatic Pressure Gas cut mud does not indicate that the well is kicking, unless it is associated with pit gain. Drilled cuttings from which the gas comes may increase mud column. ……..…......... ……..…......... ……... 0 psi Gas cutting result is only a small drop in the hydrostatic pressure. Mud Pump
- 59. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 59 LOSSES
- 60. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 60 LOSSES
- 61. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 61 LOSSES
- 62. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 62 LOSSES
- 63. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 63 SWABBING
- 64. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 64 WHAT IS SWABBING? PSI Swabbing is a temporary drop in BHP as the string is pulled upwards.
- 65. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 65 SWABBING Main causes; • Pull pipe too fast • Balled bit/BHA • Viscous mud • Narrow annulus All these make it more difficult for mud to move past the bit to fill space created by pulling drill string.
- 66. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 66 Swab Pressure Bottom Hole Pressure = Mud Hydrostatic - Swab Pressure
- 67. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 67 PSI 5000 4800 Temporary increase of fluid hydrostatic while tripping in as mud tries to move up around the bit SURGING THE OPPOSITE OF SWABBING IS SURGING As mud is forced into one formation, formation fluid may flow into the well from another
- 68. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 68 Surge Pressure Bottom Hole Pressure = Mud Hydrostatic + Surge Pressure
- 69. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 69 Surface indications of swabbing •Swabbing can be recognized by • incorrect hole fill •Monitoring the trip tank is of vital importance
- 70. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 70 Actions to be taken if swabbing is observed • The acknowledged procedure is:- • Flow check • If negative, run back to bottom • Circulate bottoms up (consider taking returns via the choke)
- 71. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 71 Effect of Pipe Slugging FLOW LINE RIG FLOOR AFTER SLUG HAS U-TUBED BACKFLOW TO TRIP TANK = VOLUME OF EMPTY PIPE FLOW LINE RIG FLOOR BEFORE SLUG HAS U-TUBED FLOW LINE RIG FLOOR HEAVY SLUG KEEPS MUD LEVEL INSIDE PIPE BELOW RIG FLOOR (Pulling ‘DRY’)
- 72. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 72 What will happen as the formation is penetrated? Shallow Gas
- 73. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 73 SHALLOW GAS
- 74. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 74 SHALLOW GAS INCEDENT
- 75. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 75 Wind Direction Diverting Shallow Gas Top Hole …......... …......... …........... TOP Hole drilling and shallow gas
- 76. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 76 KICK WARNING SIGNS
- 77. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 77 WHAT IS A KICK WARNING SIGN? A WARNING SIGN TELLS YOU: THE WELL MAY BE GOING “UNDERBALANCED” OR YOUR SAFETY MARGIN IS GETTING LESS.
- 78. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 78 Formation Pressure 9.0ppg Mud Weight 10.0 ppg What is happening? Drilling normally pressured shale Overbalance WARNING SIGNS
- 79. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 79 Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS What is happening? As the formation pressure gets closer to the mud weight, we will observe changes in; ROP Hole condition Gas levels Cuttings properties Mud properties
- 80. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 80 GEOLOGRAPH CHART Increasing Drill Rate (ROP) 9850’ 9855’ 9860’ 9.00 9.15 9.30 Increased drilling rate Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS
- 81. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 81 BIT Increased drill string torque and drag Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS
- 82. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 82 Cuttings size & shape Drilled cuttings Cavings Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS
- 83. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 83 Flowline temperature Normal Pressure Abnormal Pressure Temperature Increase Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS
- 84. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 84 Shale density Normal Pressure Increasing Formation Fluid Pressure Increasing Shale Density 9500’ 9700’ 9900’ 10100’ 9600’ 9800’ 10000’ 10200’ Normal Trend Line Shale Shale Shale Sand Sand Sand Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS
- 85. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 85 Background & connection gas 5% 10%15% 1.00 2.00 3.00 4.00 5.00 6.00 Hours 1.00 2.00 3.00 4.00 5.00 6.00 Hours BACKGROUND GAS CONNECTION GAS Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing WARNING SIGNS
- 86. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 86 Kick warning signs while tripping Hole is not taking correct amount of fluid Hole is not giving correct amount of fluid
- 87. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 87 Trip Tank TRIP TANK PUMP Trip Tank Level Stands Pulled
- 88. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 88 What should we do? Mud Weight 10.0 ppg Formation Pressure 10.0ppg Formation Pressure 9.0ppg Pressure and Porosity Increasing Flow Check Circulate Bottoms Up Raise Mud Weight Warning Signs
- 89. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 89 Flow Check Procedure This confirms that a kick is in progress. If any of the previously mentioned signs occur, either singly or together, a flow check should be carried out to confirm the situation. Pick up and space out Shut down the pumps Line up the well on the trip tank Check for flow while reciprocating the drill string Record the depth, time and duration of the flow check
- 90. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 90 KICK INDICATORS
- 91. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 91 Indicators Tripping Excessive flow from the well when tripping Drilling Increase in return mud flow from the well Increase in rate of penetration (ROP) Increasing in pit volume Decrease in pump pressure / increase in pump strokes Flow from the well with pumps off
- 92. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 92 PADDLE GAUGE on Driller’s Console KICK INDICATORS
- 93. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 93 PADDLE GAUGE on Driller’s Console KICK INDICATORS
- 94. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 94 KICK INDICATORS GAUGE on Driller’s Console
- 95. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 95 GAUGE on Driller’s Console KICK INDICATORS
- 96. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 96 TOTAL PUMP PRESSURE PSI = Surface Line friction PSI = Drillstring friction PSI = Bit (jet nozzle) friction PSI = Annulus friction PSI Total Pump Pressure
- 97. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 97 WHAT AFFECTS PRESSURE LOSS PSI PSI 30 SPM 50 SPM
- 98. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 98 WHAT AFFECTS PRESSURE LOSS PSI PSI 30 SPM 30 SPM 10 ppg 15 ppg
- 99. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 99 WHAT AFFECTS PRESSURE LOSS PSI PSI Low Vis. High Vis.
- 100. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 100 WHAT AFFECTS PRESSURE LOSS PSI PSI 50 SPM 50 SPM Large nozzle Small nozzle
- 101. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 101 WHAT AFFECTS PRESSURE LOSS PSI PSI Hole size
- 102. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 102 ANNULUS PRESSURE LOSS 30 SPM PSI • Annulus pressure loss can be quite small. • 50 -300 psi • This pressure acts on hole wall and bottom • Increases with depth, pump speed, hole size and pipe size.
- 103. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 103 EFFECT ON BOTTOM HOLE PRESSURE 90 SPM PSI • If Annulus friction = 150 psi. • Mud Weight = 11 ppg • TVD = 8700 ft • What is the pressure on the bottom of the hole? = (11 x .052 x 8700) + 150 = 5126 psi
- 104. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 104 BOTTOM HOLE PRESSURE Static Dynamic
- 105. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 105 • Circulating out a kick With Slow Rate. • Why? • minimize annular pressure loss • reaction time when manipulating choke • mud mixing • limitations of surface lines & MGS • mud pump maximum pressure limit • What pump rate do we use? Normally 2 - 5 barrels per minute CIRCULATING SYSTEM
- 106. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 106 • How? • Bit just off bottom • use drill pipe gauge on choke panel • rotate? • When? • At beginning of every shift • mud property changes • every 500 feet • bit, BHA etc. changes CIRCULATING SYSTEM
- 107. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 107 What factors determine the SPM chosen to kill the well •Maximum pressure the pump can handle •Ability to mix kill mud •Size of choke and choke line •Viscosity of the mud CIRCULATING SYSTEM
- 108. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 108 SUBSEA WELL CONTROL CONSIDERATIONS
- 109. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 109 • Pump down drillstring with returns up riser to obtain SCRP at various speeds. • SCRP used in calculating ICP and FCP on kill sheet. DETERMINING SLOW CIRCULATING RATE PRESSURE (SUBSEA) 600 psi 30 spm: SCRP Riser
- 110. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 110 • Line up equipment to pump down kill line and up choke line. Open choke fully. • Pump at same pump rates used to obtain SCRP’s. • Pressure on gauge divided by 2 is CLFP. • Important to close a ram below choke line outlet. DETERMINING CHOKELINE FRICTION PRESSURE (SUBSEA) K C 0 30 spm 400
- 111. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 111 • Line up surface equipment to pump down choke line with returns up the riser. • Pressure on choke manifold gauge is CLFP. • Obtain CLFP at same pump rates used in obtaining SCRPs. • Other methods exist but this is fastest, simplest technique and does not exert excess pressure on formation. How to Measure CHOKE LINE FRICTION PRESSURE (SubSea) Marine Riser 0 200 0
- 112. January 2021 FIS – DWC – PPT – P&P – D/1 – L 2 Version (0) 112 • Before drilling float collar and shoe take normal SCRP’s down drillstring with returns up riser • Line up equipment and take SCRP’s through chokeline (with choke fully open) • CLFP =SCRPchokeline – SCRPriser • Note: Regardless of method used, CLFP must be adjusted for increases in mud weight. New CLFP ) ppg ( M.W. Old ) ppg M.W.( New × CLFP = 600 psi Riser Open 800 psi Subsea BOP Returns APL Negligible CL FL 200psi (dynamic) 0 Riser Closed CHOKE LINE FRICTION PRESSURE (SubSea)
Editor's Notes
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- #51: 13
- #52: 12
- #53: 8
- #54: 13
- #55: Failure to Keep the hole Full This particular cause of well kicks is one, which should never happen today, but it still does. When a stand of drill pipe is pulled from the well, the volume of the metal pulled must be replaced with drilling fluid. If this is not done, the level of the drilling fluid in the well will drop. Since the bottom hole hydrostatic pressure is the product of the drilling fluid density multiplied by the height of the column, the bottom hole hydrostatic pressure will reduce if the height of the column is reduced. If this reduction in height is appreciable, the bottom well hydrostatic pressure may be reduced to such an extent that the safety margin may be taken away and the well may kick. Different measurements can indicate if the proper amount of drilling fluid is pumped into the well. One possibility is a pit volume monitoring, but large pits will not show small changes; these can best be seen in trip tanks. This is one or more high tanks with a little cross-section, where a little change in volume is easy to see. It should be near the rig floor and calibrated so the Driller can easily see and compare the volumes pumped into the well versus steel pulled out. Another possibility is that the Driller by help of a stroke counter can check the amount of drilling fluid pumped into the well from the pits.
- #56: 16
- #57: Expansion of Gas Although some kicks are predominantly salt water or oil, at least some gas is usually present. Because salt water and oil do not expand as pressure decreases, they are not as troublesome as gas. It is important for the persons who control blowouts to understand the behavior of gas in a well. The gas volume change as a result of pressure change is predictable, and this allows calculation under illustrative conditions of changes in bottom well pressure as gas rises through the drilling fluid. When the pressure of a given mass of gas is doubled, the volume is halved. When the pressure is halved the volume is doubled. This relationship between pressure and volume results in the greatest expansion of the gas in the upper part of the well. Although gas-cut drilling fluid is one of the early indicators of abnormal pressure, minor gas cutting results in only a small reduction in the hydrostatic head. In a gas-cut column of drilling fluid, the pressure increases rapidly with depth, so that the volume of gas scattered through the well bore is very small, and reduces the overall drilling fluid density in the well very little. A slug of gas in the bottom of a well is potentially dangerous, because it will expand greatly when it rises or is pumped up. Under low pressure near the surface, it will displace a large amount of drilling fluid from the well and consequently greatly reduce bottom hole pressure giving risk for a blowout. The safe handling of a gas kick requires knowledge about the principle of gas expansion and consequently lowering the pressure in the gas bubble as it is circulated up through the annulus in order to maintain the correct and constant bottom hole pressure. The theoretical knowledge requires practice as well as knowledge about well control equipment. When the gas in a well control situation is circulated to the surface and expanding, more drilling fluid must be allowed to flow out of the annulus than is pumped into the drill pipe. Thus, the pit level will increase. The expected drilling fluid volume increase should be known prior to circulating out the kick. This detail is discussed in the kick control section. To control a correct and constant bottom hole pressure, the surface pressures are used as a parameter for control. This is done by means of the choke in connection with a stroke counter for the mud pumps, and simple recognized procedures.
- #59: 16
- #65: Swabbing is a temporary drop in BHP as the string is pulled upwards. This drop in pressure is caused by the friction of the mud moving downwards past the pipe.
- #79: As we start to drill the shale with a mud weight of 10.0 ppg, formation pressure is still normal. We are overbalance.
- #80: As the formation pressure in the shale increases, we lose the overbalance until we are drilling “on balance”. Changes in parameters will be observed: - ROP - Hole condition - Gas levels - Cuttings properties - Mud properties. Discuss with class.
- #81: While drilling normally pressured shales and assuming constant parameters such as; - Bit type - WOB - RPM - Mud weight - Hydraulics program a decrease in ROP would be expected. When abnormal pressure is encountered; - overbalance decreases - porosity increases - density decreases. This can cause a gradual increase in the ROP.
- #82: As the formation pressure increases,the plastic clay will start to squeeze into the hole, causing increased torque and drag. This is often known as “heaving” or “sloughing”. It must be remembered that heaving shale by itself may be due to many causes other than overpressure.
- #83: Normal drilled cuttings tend to be small and flat with rounded edges. As the formation pressure increases, cuttings become long and splintery with angular edges. As the overbalance decreases, the cuttings start to explode off the side of the hole by themselves - CAVINGS.
- #84: Bottom hole temperature normally increases as we drill deeper. This is due to the flow of heat from the core of the Earth. This gives us a “temperature gradient”. The higher porosity and larger amounts of fluid in an overpressured shale will act as an insulating layer, disrupting the temperature gradient. Thus the temperature appears to increase more rapidly through the overpressured zone. The practical limitations of measuring mud temperature at the flowline, however, generally mask this effect.
- #85: Shale density should normally increase with depth. The increased porosity and fluid content of the overpressured zone will show a deviation from this trend.
- #86: As the porosity increases background gas will also increase (assuming the pore spaces are full of gas). We must remember however that the pore spaces may be full of water, in which case gas levels will not increase. Connection gas may also begin to occur as we approach balance.
- #106: We would not normally consider circulating out a kick at the same pump rate as drilling. We use a Slow Circulating Rate (SCR). Why? - Minimise pressure - Reaction times - Mud mixing - Limitations of MGS
- #107: We would not normally consider circulating out a kick at the same pump rate as drilling. We use a Slow Circulating Rate (SCR). How? - Bit just off bottom - Use drill pipe gauge on choke panel - Rotate?