44. Bit record form Rig site daily drilling report form Office drilling report Computerized drilling information network

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Shawn Hensley
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1 Figures v Tables vii Foreword ix Acknowledgments xi Units of Measurement xii Introduction 1 Well Planning 5 Bits 9 Bit Selection 9 Bit Design 11 How Bits Drill 12 Roller Cone Bits 13 Natural Diamond Bits 19 Fixed-Cutter Bits 21 Hybrid Bits 23 Special Purpose Bits 24 Bit Classification 26 Dull Bit Evaluation 33 Drilling Performance Records 45 Weight on Bit and Rotary Speed 51 Special Considerations 57 Rate of Penetration Control 65 Drilling Mud 71 Mud Characteristics that Affect ROP 73 Air or Gas Drilling 83 Air Drilling Equipment 84 Bit Hydraulics 91 Hydraulics Calculations 94 Formation Properties 101 New Technology 107 Glossary 111 Review Questions 131 Answers to Review Questions 137 contents iii

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3 1. IADC footage drilling bid-contract 2 2. Factors affecting penetration rate 4 3. The learning curve for drilling offshore development wells 5 4. A recommended bit or well program 9 5. A rig site integrated drilling system for measurement-while-drilling (MWD) Bits Drilling action of bits Combination journal and ball bearings in a roller cone bit showing the journal angle The rows of cutters on one cone intermesh with the cutters on the other cones Cone offset. Each cone rotates on its own axis Soft-formation milled-tooth bit Tungsten carbide inserts Soft-formation insert bit Medium-formation insert bit Hard-formation insert bit Flat tungsten carbide gauge row inserts Four parts of a diamond bit Natural diamond bit showing watercourses A polycrystalline diamond compact (PDC) Six-blade PDC bit Detail of PDCs set in blade Combination TSP and natural diamond bit Diamond-impregnated pad set in gauge surface of bit body Diamond-impregnated stud backup to a PDC cutter Ream-while-drilling bits Air hammer bits Special purpose bits Steerable directional drilling bit Industry accepted PDC bit profiles Cutter wear measurement Gauge ring measurement using the two-thirds rule An evenly worn dull bit, which is in gauge Cone dragging or skidding caused by a locked cone Cracked cone Cone erosion Off-center wear Center coring Broken inserts Heat checking (small cracks) on insert cutters Steel tooth breakage Self-sharpened tooth wear Bit gauge wear or rounding Undergauge hole caused by bit gauge wear or rounding 43 Figures v

4 vi 44. Bit record form Rig site daily drilling report form Office drilling report Computerized drilling information network Effect of rotary RPM on drilling rate Dogleg produced by reduced weight Rotary drive power required at various torque loads and RPM Tension and compression on drill string during rotation Cut-away drawing of a downhole motor powered by drilling mud Turbodrill design Drilling assembly using a downhole motor and a bent sub Horizontal turn radii Short radius articulated downhole motor equipped with PDC bit Adjustable kick-off (AKO) downhole motor assembly can be used for drilling vertical to short-radius horizontal holes Geolograph TM chart. Note drilling break at 4,915 feet where average ROP decreases from average 6.5 min/ft to 3.5 min/ft Pick-up and slack-off chart Functions of drilling mud Daily drilling mud report (water base mud) from previously drilled well. Computerized report as printed out at rig site by mud engineer Effect of mud weight on drilling rate Effect of mud solids on drilling rate Buildup of filter (mud) cake on borehole walls. Solid particles in the drilling mud plaster the wall of the hole forming an impermeable barrier Skid-mounted air compressors for air drilling Air drilled cuttings blown through a blooey line with flare set to ignite any gas encountered Air hammer (percussion) drilling tool Arrangement of equipment for air drilling Blowout preventers and lines for air drilling Hydraulic power losses in rig mud system Factors affecting rig hydraulics Overburden (formation pressure increases with depth) Drilling through alternating hard and soft zones can produce offset ledges In formations with dip of less than 45 degrees, the bit tends to drift or walk up-dip Faster drilling may be achieved if the bit is allowed to drift into the target area In formations with dip of 45 degrees or more, the bit tends to drift (slide) down-dip along bedding planes Single-cone bit for drilling small diameter holes 109

5 1. Steel tooth bit specifications relative to formation type Insert bit specifications relative to formation type IADC roller cone bit classification chart IADC classification chart for PDC bits IADC classification chart for TSP and natural diamond bits Tooth bit comparison chart IADC dull grading chart Typical weights and RPMs for roller cone bits Typical specifications and operating guidelines for natural diamond bits run on downhole mud motor Sample drill-off test in sandy shale Mud density conversion table Mud-weight adjustment with barite or water Approximate rate of circulation in ft 3 /min in 8¾-inch hole (m 3 / min in 222-mm hole) with 4½- inch (114-mm) drill pipe with volumes to produce lifting power equivalent to a velocity of 3,000 ft 3 /min (915 m 3 /min) Pressure losses as illustrated in figure 70 with mud pumping rate of 400 gal/min at 2,000 psi (1.5 m 3 /min at 13,791 kpa) Determining pressure loss through drill stem bore 96 15A. Determining pressure loss through drill stem bore (metric) Determining pressure drop in psi across bit nozzle 98 16A. Determining pressure drop in kpa across bit nozzle (metric) 99 Tables vii

PDC Drill Bits. Drilling Equipment Made in Germany

PDC Drill Bits. Drilling Equipment Made in Germany PDC Drill Bits Drilling Equipment Made in Germany www.micon-drilling.de Phone +49. 51 44. 49 36 0 MICON-Drilling GmbH Im Nordfeld 14, 29336 Nienhagen, Germany www.micon-drilling.de Copyright 2016 MICON-Drilling.