Field Development Project of E11 drilling dept.ppt
- 2. Drilling Department Presented By: Muhammad Noman Khan s/o Muhammad Hanif Khan 2
- 3. Presentation Synopsis 1. Pressure and fracture gradient determination 2. Calculation and selection of casing type (Proposed casing programmed) 3. Cementing Plan 4. Mud Plan 5. Bit Plan 6. Well Head Housing 7. Rig selection 8. Drill time estimation 3
- 4. 1. Type of completion for production well 2. Well completion equipment 3. Packer Selection 4. Wellhead and Christmas Tree 5. Perforation 6. Completion and Packer Fluid 7. Summary Completion Goal 4
- 5. Formation & Fracture Pressure 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 500 1000 1500 2000 2500 3000 DEPTH(FT) PRESSURE (PSI) Fracture Pressure (psi) Formation Pressure Gradient (psi) Pressure gradient Formation pressure Overburden 0.442 psi/ ft 1 psi/ ft • Formation pressure • Depth • Method used to determine fracture gradient : Eaton’s Method 5
- 6. Type of Casing Casing Size, in Casing Grade Casing Weight, lb/ft OD, in ID, in Body Yield Strength, lb Conductor 30 X-52 310 30 28 1685000 Surface 20 J-55 94 20 19.124 1480000 Production 9 5/8 N-80 40 9 5/8 8.535 800000 Casing Program – Producer Well 6
- 7. Type of Casing Casing Size, in Casing Grade Casing Weight, lb/ft OD, in ID, in Body Yield Strength, lb Conductor 30 X-52 310 30 28 1685000 Surface 20 J-55 94 20 19.124 1480000 Production 9 5/8 N-80 40 9 5/8 8.535 800000 Casing Program – Injector Well 7
- 8. Hole Size, in Casing Size Mud Type Mud Weight, ppg Total Amount, bbl 36 30” Seawater, Sweep/Pad mud 9.5 850 26 20” Seawater, Sweep/Pad mud 10 1400 12 ½” 9 5/8” KCL Polymer Mud 12 665 Mud Plan 8
- 11. Hole Size Casing Size Total Volume Cu.Ft In BBL Total Sk of Cement 36” 30” 1033.47 ft3 184 bbl 675 sk Additives ( To be mixed with Mixed Water) Water Req Slurry Yield Required 4% Bentonite 7.6 gal/sk 1.53 ft3/ sk 2540 lbs Defoamer ( D Air 3000L) 0.05 gal/sk 34 gal Dispersant (CFR – 3L) 0.07 gal/sk 47 gal Cement Plan for 30” 11
- 12. Hole Size Casing Size Total Volume Cu.Ft In BBL Total Sk of Cement 26” 20” 965 ft3 406 BBL 934 sk Water Req Slurry Yield Mix Water Tune Lite Cement 7.4 gal/sk 2.440 ft3/sk 8.31 gal/sk Anti Gas Migration (GasStop Exp) 0.06 gal/sk 56 gal Defoamer ( D Air 3000L) 0.05 gal/sk 34 gal Dispersant (CFR – 3L) 0.07 gal/sk 47 gal Cement Retarder (SCR 500L) 0.25 gal/sk 235 gal Fluid Loss Additive (Halad-413L) 0.20 gal/sk 185 gal Cement Plan for 20” Lead 12
- 13. Hole Size Casing Size Total Volume Cu.Ft In BBL Total Sk of Cement 26” 20” 2280 ft3 172 BBL 840 sk Water Req Slurry Yield Mix Water G Neat Cement 4.91 gal/sk 1.150 ft3/sk 5.01 gal/sk Defoamer ( D Air 3000L) 0.1 gal/sk 84 gal Cement Plan for 20” Tail 13
- 14. Hole Size Casing Size Total Volume Cu.Ft In BBL Total Sk of Cement 12 1/2” 9 5/8” 1011 ft3 140 BBL 415 sk Water Req Slurry Yield Mix Water Tune Lite Cement 7.4 gal/sk 2.440 ft3/sk 8.31 gal/sk Anti Gas Migration (GasStop Exp) 0.13 gal/sk 55 gal. Defoamer ( D Air 3000L) 0.1 gal/sk. 45 gal. Dispersant (CFR – 3L) 0.09 gal/sk. 40 gal. Cement Retarder (SCR 500L) 0.40 gal/sk 166 gal Fluid Loss Additive (Halad-413L) 0.30 gal/sk 125 gal Cement Plan for 9 5/8” Lead 14
- 15. Hole Size Casing Size Total Volume Cu.Ft In BBL Total Sk of Cement 12 1/2” 9 5/8” 225 ft3 40 BBL 196 sk. Water Req Slurry Yield Mix Water G Neat Cement 4.91 gal/sk 1.150 ft3/sk 5.01 gal/sk Defoamer ( D Air 3000L) 0.1 gal/sk 20 gal Cement Plan for 9 5/8” Tail 15
- 16. Volumetric mixing controls. Q1 = mixwater rate; Q2 = dry solids rate; Q3 = slurry rate Tune Lite Mixing & Cement Head 16
- 17. Hole Size, in Bit Type Bit Size, in 36 Mill Tooth, Hole Opener 36” 26 Tricone Roller 26” 12 ½” TD506 PDC 12 ½” Bit Planning 17
- 18. Bit Planning 18
- 19. Bit Planning 19
- 21. Drillship Aban Ice Semi Submersible Blackford Dolphin Rigs 21
- 22. B1 B2 B3 B4 B5 B6 B7 B8 B9 Top Section 30” 30” 30” 30” 30” 30” 30” 30” 30” 20” 20” 20” 20” 20” 20” 20” 20” 20” Estimated Time (Days) 13 13 13 13 13 13 13 13 13 Total Time to Complete Top Section for all Wells – 117 days 13 days including Rig move and prepare to drill De-hire Drillship after completion of Top Sections Drilling Time Estimation 22
- 23. B1 B2 B3 B4 B5 B6 B7 B8 B9 Lower Section 13 3/8” 13 3/8” 13 3/8” 13 3/8” 13 3/8” 13 3/8” 13 3/8” 13 3/8” 13 3/8” 9 5/8” 9 5/8” 9 5/8” 9 5/8” 9 5/8” 9 5/8” 9 5/8” 9 5/8” 9 5/8” Estimated Time (Days) 25 25 25 25 25 25 25 25 25 Total Time to Complete Top Section for all Wells – 225 days 25 days including Rig move and prepare to drill and Running BOP De-hire Semi Sub after completion of Lower Sections Drilling Time Estimation 23
- 24. • Pipe Sticking • Differential-Pressure Pipe Sticking • Mechanical Pipe Sticking • Loss of Circulation • Drillpipe Failures • Twistoff • Fatigue • Pipe-Failure Prevention • Hydrogen-Sulfide-Bearing Zones and Shallow Gas • Since we don’t have log data, we very much depend on the real time drilling operations, Hence we have to be very careful about gas kick or loss. Drilling Challenge 24
- 25. • Fire-fighting equipment must be available for emergency use in the event of a fire and should be provided in first-class working order. • Unauthorized person should not be allowed to be on the rig at any time. • Personnel who not involved directly in the particular operation should keep away from operation site. • Sea survival and offshore course is compulsory for all personnel. Safety 25
Editor's Notes
- #9: A Polymer drilling fluids provide inhibition against reactive formations by providing viscosity, without the need for bentonite, when using inhibitors such as Potassium Chloride, glycols and amines. Bentonite will not yield in the presence of the inhibition agents. Potassium Chloride is also very important for maintaining permeability after filtrate invasion.