eXtreme® Rotary Shoulder Handbook D RILLING P RODUCTS & S ERVICES www.grantprideco.com CONTENTS SECTION I Drill Pipe SECTION II Double Shoulder Connections SECTION III Heavy Weight Drill Pipe SECTION IV Drill Collars SECTION V Kellys SECTION VI Subs SECTION VII Well Control This handbook is a summary of the technical data from API Spec. 7 Latest Edition, API RP 7G Latest Edition, etc., for the purpose of easier application in the field. Grant Prideco has produced this handbook for general information only. It is not intended for design and engineering purposes. Although every effort has been made to maintain the accuracy and reliability of its contents, Grant Prideco in no way assumes responsibility or liability for any loss, damage or injury resulting from the use of information and data herein. All applications for the material described are at the user's own risk and are the user's responsibility. Proper break-in is probably the most important factor affecting the life of the tool joint connection. Here are some recommendations to follow: 1. Proper make-up torque is determined by the connection type, size, OD and ID and may be found in torque tables. 2. Make up connections slowly, preferably using chain tongs. (High speed kelly spinners or the spinning chain used on initial make-up can cause galling of the threads). 3. Tong them up to the predetermined torque using a recently calibrated torque gauge to measure the required line-pull. Note: Monitor breakout torque. It should be less than or no greater than make-up torque. If it is greater, the connection should be cleaned, inspected and repaired, before it is made up again. 4. Breakout, visually inspect, redope and make up two more times before running in hole. Always use backup tongs to make and break connections. 5. Stagger breaks on each trip so that each connection can be checked, redoped and made up every second or third trip, depending on the length of drill pipe and size of rig. A new string of drill pipe deserves good surface handling equipment and tools. Check slips and master bushings before damage occurs to the tube. (See the IADC Drilling Manual for correct measurements). Do not stop the downward movement of the drill stem with the slips. This can cause crushing or necking down of the drill pipe tube. The drill pipe can also be damaged by allowing the slips to ride the pipe on trips out of the hole. Good rig practices will help eliminate time consuming trips in the future, looking for washouts or fishing for drill pipe lost in the hole. For more information refer to the IADC Drilling Manual. 1 DRILL PIPE Drill Pipe New Tool Joints Torque Chart Drill Pipe Tool Joint Drill Pipe Size (in) 2 3/8 2 7/8 Type Conn 4 Pin ID (in) Make-up Torque (ft-lb) N.C. 26 (I.F.) O.H. O.H. S.L. H-90 W.O. P.A.C. 3 3 3 3 3 2 3 /8 /4 1 /8 1 /4 3 /8 7 /8 1 3/4 1 3/4 2 2 2 1 3/8 3,900 3,700 2,600 2,700 2,400 2,600 2 7/8” S.H. (N.C. 26) O.H. O.H. S.L. H-90 S.L. H-90 P.A.C. W.O. X.H. N.C. 31 (I.F.) N.C. 31 (I.F.) N.C. 31 (I.F.) 3 3 3 3 3 3 4 4 4 4 4 3 /8 /4 7 /8 7 /8 7 /8 1 /8 1 /8 1 /4 1 /8 1 /8 3 /8 1 2 2 2 2 1 2 1 2 2 1 3 3,900 3,100 4,800 3,800 6,800 3,200 3,900 7,000 6,400 7,100 4,400 3 /2 S.H. (N.C. 31) S.L. H-90 S.L. H-90 O.H. O.H. N.C. 38 (W.O.) N.C. 38 (I.F.) N.C. 38 (I.F.) N.C. 38 (I.F.) N.C. 38 (I.F.) N.C. 40 (4” F.H.) N.C. 40 (4” F.H.) N.C. 40 (4” F.H.) 4 4 4 4 4 4 4 5 5 5 5 5 5 1 2 3 2 3 2 3 2 2 2 2 2 2 2 1 S.H. (3 1/2” X.H.) O.H. O.H. N.C. 40 (4” F.H.) N.C. 40 (4” F.H.) N.C. 40 (4” F.H.) N.C. 40 (4” F.H.) N.C. 46 (W.O.) N.C. 46 (I.F.) N.C. 46 (I.F.) N.C. 46 (I.F.) N.C. 46 (I.F.) N.C. 46 (I.F.) N.C. 46 (I.F.) N.C. 46 (I.F.) 4 5 5 5 5 5 5 5 6 6 6 6 6 6 6 5 2 3 3 2 2 2 2 3 3 3 3 3 3 2 2 9 1 3 1/2 Box OD (in) 1 3 /8 5 /8 5 /8 3 /4 3 /4 3 /4 3 /4 1 /4 /8 /2 3 1 /8 /4 1 /2 1 /4 1 /4 1 /2 1 /2 3 /4 1 /4 /16 /32 7 /16 5 /32 1 /2 7 /16 7 /8 1 /8 7 5 5 /8 /8 11 /16 11 /16 11 /16 /16 /16 1 /8 9 /16 7 /16 1 /4 9 7 /16 15 /32 1 /4 13 /16 11 /16 7 /16 7 /16 7 /16 1 /4 1 /4 5 /8 /8 7 6,400 7,600 11,110 6,500 9,300 6,800 9,700 10,700 11,700 14,000 14,600 15,600 17,100 8,100 11,900 14,700 12,400 13,500 15,600 15,600 15,200 17,600 20,500 20,500 17,600 20,500 24,400 21,900 Note: 1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on Slim Hole (S.H.) tool joints due to special service requirements. 2. Make-up torque values may be lower than those published in API RP 7G Latest Edition. The make-up values are lower due to the combined torsional and tensile loads found in service conditions. 2 Used Tool Joints Torque Chart Drill Pipe Tool Joint Premium Box OD (in) 3 1/4 3 1/16 3 2 31/32 3 1/16 2 25/32 3 3 3 3 3 3 3 3 3 3 4 4 4 4 4 4 4 4 4 4 4 4 5 5 4 4 5 4 4 5 5 5 5 5 5 5 5 5 5 3 /8 /2 19 /32 17 /32 19 /32 1 /8 5 /8 23 /32 11 /16 29 /32 1 /16 1 3 /16 3 /8 9 /32 3 /8 3 /8 3 /8 19 /32 21 /32 23 /32 15 /32 3 /32 7 /16 31 /32 1 /32 13 /16 15 /16 7 /32 /32 /16 15 /32 9 /32 9 /16 5 /8 5 /8 5 7 Class 2 Make-Up Torque (ft-lb) Box OD (in) Make-up Torque (ft-lb) 3,000 2,300 1,800 2,000 2,000 2,500 3 3/16 3 1/32 2 31/32 3 31/32 3 2 23/32 4,100 3,300 4,300 3,800 4,600 3,500 3,200 4,400 3,200 5,700 7,700 3 3 3 3 3 3 3 3 3 3 3 5 6,900 5,500 8,800 5,500 7,000 5,300 5,300 8,800 9,900 10,900 11,400 12,600 14,400 3 4 4 4 4 4 4 4 4 4 4 4 4 29 /32 /8 /32 7 /32 5 /16 11 /32 11 /32 1 /2 9 /16 5 /8 13 /32 7 /8 15 /16 5,700 4,500 7,100 4,600 6,000 4,800 4,800 7,300 8,300 9,300 9,000 10,200 11,400 8,800 7,500 8,800 9,000 11,400 12,600 12,600 7,900 10,000 12,800 13,600 9,200 15,800 17,300 17,300 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 11 7,400 6,200 7,500 7,300 9,000 10,200 10,200 6,500 7,900 10,000 11,400 7,200 12,800 14,300 14,300 /16 /16 17 /32 17 /32 17 /32 1 /16 9 /16 21 /32 21 /32 13 /16 31 /32 7 1 9 /32 /32 /32 23 /32 13 /16 7 /8 7 /8 5 /32 7 /32 5 /16 3 /8 3 /16 7 /16 1 /2 1 /2 29 31 2,500 2,100 1,600 2,000 1,500 2,100 3,600 2,700 3,600 3,800 3,800 3,500 2,500 3,700 2,800 4,600 6,500 Note: 3. Make-up torque is based on the use of 40% to 50% by weight of finely powdered metallic zinc, applied to all threads and shoulders. 3 New Tool Joints Torque Chart Drill Pipe Tool Joint Drill Pipe Size (in) 1 4 /2 5 5 1/2 6 5/8 Type Conn Box OD (in) 7 (X.H.) (X.H.) (X.H.) (X.H.) (I.F.) (I.F.) (I.F.) (I.F.) (I.F.) 5 6 6 6 6 6 6 6 6 6 6 6 6 N.C. 50 (X.H.) N.C. 50 (X.H.) N.C. 50 (X.H.) N.C. 50 (X.H.) N.C. 50 (X.H.) 5 1/2” F.H. 5 1/2” F.H. 5 1/2” F.H. 6 6 6 6 6 7 7 7 3 F.H. F.H. F.H. F.H. F.H. F.H. F.H. F.H. 7 7 7 7 7 7 7 7 F.H. F.H. F.H. F.H. F.H. F.H. F.H. F.H. 8 8 8 8 8 8 8 8 O.H. F.H. F.H. F.H. N.C. 46 N.C. 46 N.C. 46 N.C. 46 N.C. 50 N.C. 50 N.C. 50 N.C. 50 N.C. 50 /8 1 /4 /4 /4 1 /4 3 /8 3 /8 3 /8 3 /8 3 /8 1 1 /8 /8 1 /2 1 /2 5 /8 3 1 /4 /4 1 1 /4 /4 1 /4 1 /2 1 /2 1 1 /4 /4 1 /4 1 /2 1 /2 1 Pin ID (in) 3 3 2 2 3 3 2 2 3 3 3 3 2 3 /4 /2 /4 3 /4 5 /8 1 /2 7 /8 14,600 17,600 20,100 22,300 17,600 20,500 23,200 25,600 19,800 19,800 21,600 23,400 30,300 33/4 3 1/2 3 1/4 3 2 3/4 3 1/2 3 1/2 3 1/4 19,800 23,400 26,800 30,000 32,900 37,400 37,400 41,200 4 4 3 3 3 3 3 3 29,200 29,200 33,400 37,400 37,400 37,400 44,600 44,600 5 5 5 4 4 4 4 4 /4 Make-up Torque (ft-lb) 3 /4 /2 /4 1 1 3 1 3 3 /4 /2 /2 1 /2 1 1 3 /4 /4 3 /4 1 /4 1 /4 3 38,400 38,400 38,400 44,600 44,600 44,600 56,100 56,100 Note: 1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on Slim Hole (S.H.) tool joints due to special service requirements. 2. Make-up torque values may be lower than those published in API RP 7G Latest Edition. The make-up values are lower due to the combined torsional and tensile loads found in service conditions. 4 Used Tool Joints Torque Chart Drill Pipe Tool Joint Premium Box OD (in) Class 2 Make-Up Torque (ft-lb) Box OD (in) Make-up Torque (ft-lb) 5 5 5 5 5 5 5 5 5 5 5 5 6 15 /32 /8 9 /16 5 /8 13 /32 19 /32 25 /32 23 /32 29 /32 23 /32 13 /16 15 /16 7 /32 12,300 12,100 16,400 17,800 12,100 16,500 21,200 19,600 16,600 11,600 14,100 17,500 25,500 5 5 5 5 5 5 5 5 5 5 5 5 6 3 /8 /32 /16 15 /32 5 /16 15 /32 5 /8 9 /16 25 /32 21 /32 23 /32 27 /32 1 /16 10,000 10,100 13,500 14,200 9,900 13,500 17,300 15,800 13,200 10,000 11,600 14,900 21,000 5 6 6 6 6 6 6 6 7 /8 /32 /32 3 /16 5 /16 21 /32 23 /32 15 /16 15,800 20,200 21,900 24,700 27,500 25,500 27,700 35,500 5 5 5 6 6 6 6 6 25 13,300 16,700 18,400 22,000 22,900 20,200 22,300 28,800 6 6 6 6 6 6 7 7 17 /32 /16 5 /8 23 /32 25 /32 25 /32 1 /32 1 /32 21,300 22,300 24,500 27,650 29,900 29,900 39,000 39,000 6 6 6 6 6 6 6 6 7 /16 15 /32 1 /2 19 /32 5 /8 11 /16 27 /32 7 /8 18,200 19,200 20,300 23,350 24,500 26,560 32,100 33,200 7 7 7 7 7 7 7 8 7 26,800 29,500 35,100 38,000 38,000 40,900 48,200 52,700 7 3/8 7 13/32 7 1/2 7 9/16 7 19/32 7 21/32 7 25/32 7 27/64 24,100 25,500 29,500 32,300 33,700 36,500 42,300 45,200 3 1 3 9 /16 /2 5 /8 11 /16 11 /16 3 /4 29 /32 1 9 7 /32 /32 /32 29 31 1 /32 /16 /2 9 /16 3 /4 3 1 Note: 3. Make-up torque is based on the use of 40% to 50% by weight of finely powdered metallic zinc, applied to all threads and shoulders. 5 4.85 6.65 6.85 10.40 9.50 13.30 15.50 11.85 14.00 15.70 13.75 16.60 20.00 19.50 25.60 21.90 24.70 23.40 26.30 25.20 27.70 2 3/8 2 7/8 4 1/2 6 5 1/2 7/ 8 6 5/8 5 5 4 3 1/2 Nominal Weight (lb/ft) Size OD (in) 0.330 0.362 0.361 0.415 0.361 0.415 0.271 0.337 0.430 0.362 0.500 0.217 0.362 0.254 0.368 0.449 0.262 0.330 0.380 0.190 0.280 Wall Thick ness (in) 5.965 5.901 5.153 5.045 4.778 4.670 3.958 3.826 3.640 4.276 4.000 2.441 2.151 2.992 2.764 2.602 3.476 3.340 3.240 1.995 1.815 ID (in) 6.5262 7.1226 6.2535 7.1185 5.8282 6.6296 3.6004 4.4074 5.4981 5.2746 7.0686 1.8120 2.8579 2.5902 3.6209 4.3037 3.0767 3.8048 4.3216 1.3042 1.8429 19.572 21.156 16.251 18.165 14.062 15.688 7.184 8.542 10.232 11.416 14.490 2.242 3.204 3.922 5.144 5.846 5.400 6.458 7.156 1.320 1.734 Cross Polar Sectional Sectional Area Modulus of Pipe Z (sq. in) (cu in) 70,550 76,300 58,600 65,500 50,620 56,470 25,860 30,750 36,840 41,090 52,160 8,070 11,530 14,120 18,520 21,050 19,440 23,250 25,760 4,760 6,240 E75 89,360 96,600 74,200 83,000 64,120 71,530 32,760 38,950 46,660 52,050 66,070 10,220 14,610 17,890 23,460 26,660 24,620 29,450 32,630 6,020 7,900 X95 98,770 106,800 82,000 91,700 70,870 79,060 36,210 43,050 51,570 57,530 73,030 11,300 16,150 19,770 25,930 29,470 27,220 32,550 36,070 6,060 8,740 G105 127,044 137,300 105,500 117,900 91,120 101,650 46,550 55,350 66,300 73,970 93,900 20,760 25,420 33,330 37,890 34,990 41,840 46,380 489,460 534,200 469,000 533,900 437,120 497,220 270,030 330,560 412,360 395,600 530,140 135,900 214,340 194,260 271,570 322,780 230,750 285,360 324,150 E75 97,820 138,220 - 619,990 676,700 594,100 676,300 553,680 629,810 342,040 418,700 522,320 501,090 671,520 172,140 271,500 246,070 343,990 408,850 292,290 361,460 410,590 123,900 175,080 X95 685,250 747,900 656,600 747,400 611,960 696,110 378,050 462,780 577,300 553,830 742,200 190,260 300,080 271,970 380,190 451,890 323,050 399,500 453,810 136,940 193,500 G105 881,044 961,600 844,200 961,000 786,810 895,000 486,060 595,000 742,240 712,070 954,260 244,620 385,820 349,680 488,820 581,000 415,360 513,650 583,420 176,070 248,790 S135 Tensile Yield Strength (lb) S135 Torsional Yield Strength (ft-lb) New Drill Pipe Dimensional, Torsional, and Tensile Data Performance Properties of Seamless Drill Pipe 4.85 6.65 6.85 10.40 9.50 13.30 15.50 11.85 14.00 15.70 13.75 16.60 20.00 19.50 25.60 21.90 24.70 23.40 26.30 25.20 27.70 2 3/8 7 6 5/8 5 7/8 5 1/2 5 4 1/2 4 3 1/2 2 7/8 (in) Nominal Weight (lb) Size OD 4,810 5,890 11,040 15,600 10,470 16,510 10,040 14,110 16,770 8,410 11,350 12,900 7,200 10,390 12,960 10,000 13,500 8,440 10,460 7,450 9,560 E75 5,310 6,750 13,980 19,760 12,930 20,910 12,060 17,880 21,250 9,960 14,380 16,340 8,400 12,750 16,420 12,010 17,100 10,000 12,920 8,770 11,500 X95 5,490 7,100 15,460 21,840 14,010 23,110 13,050 19,760 23,480 10,700 15,900 18,050 8,950 13,820 18,150 12,990 18,900 10,740 14,000 9,360 12,410 G105 Collapse Pressure, psi 6,040 7,810 19,070 28,080 17,060 29,720 15,780 25,400 30,190 12,650 20,170 23,210 10,310 16,800 23,330 15,700 24,300 12,710 17,050 10,820 14,890 S135 6,540 7,170 10,500 15,470 9,910 16,530 9,520 13,800 16,840 8,600 10,830 12,470 7,900 9,830 12,540 9,500 13,120 8,610 9,900 8,060 9,270 E75 8,280 9,080 13,300 19,600 12,550 20,930 12,070 17,480 21,330 10,890 13,720 15,790 10,010 12,450 15,890 12,040 16,620 10,910 12,540 10,220 11,740 X95 9,150 10,040 14,700 21,660 13,870 23,140 13,340 19,320 23,570 12,040 15,160 17,460 11,070 13,760 17,560 13,300 18,380 12,060 13,860 11,290 12,980 G105 Internal Pressure, psi S135 11,770 12,910 18,900 27,850 17,830 29,750 17,150 24,840 30,310 15,480 19,490 22,440 14,230 17,690 22,580 17,110 23,620 15,510 17,830 14,520 16,690 New Drill Pipe Collapse and Internal Pressure Data Tool Joint Bevel Diameters Type Size & N.C 38 & N.C 38 5 4 37/64 N.C. 40 5 1/2 5 1/64 4 & N.C. 46 6 5 23/32 4 & N.C. 46 6 1/4 5 23/32 4 1/2 & N.C. 50 6 1/8 6 1/16 4 1/2 & N.C. 50 6 1/4 6 1/16 4 1/2 & N.C. 50 4 1/2 & N.C. 50 4 1/2 & N.C. 50 6 3/8 6 1/2 6 5/8 6 1/16 N.C. 56 7 6 47/64 3 1/2 4 31/64 4 & N.C. 40 4 5/8 5 1/4 4 1/2 6 5 23/32 5 1/2 7 5 1/2 7 1/4 6 23/32 6 23/32 5 1/2 7 1/2 7 3/32 3 1/2 4 1/2 & N.C. 46 4 3/4 4 17/32 6 5 23/32 6 1/4 5 1/2 5 59/64 6 5 23/32 3 1/4 3 1/8 3 7/8 3 23/32 4 5/8 4 7/16 3 3 Full Hole & Numbered Connections Xtra Hole & Numbered Connections H-90 & N.C 31 4 2 2 3 2 Slimhole & Numbered Connections & N.C 26 5 & N.C. 50 4 Slimline H-90 Bev. Dia 3 17/64 2 Internal Flush & Numbered Connections OD 3 3/8 4 1/8 4 3/4 2 3/ 8 7/ 8 1/ 2 1/ 2 2 3 1/ 2 3/ 8 7/ 8 1/ 2 3/ 8 7/ & N.C. 26 8 1/ & N.C. 31 2 2 3 4 4 4 4 4 4 1/2 & N.C. 38 5 8 7/ 8 3/ 8 1/ 8 1/ 2 5/ 8 3 61/64 4 37/64 6 1/16 6 1/16 5 1/64 5 17/64 2 25/32 3 17/64 3 61/64 4 11/32 4 11/32 4 37/64 Decimal and Millimeter Equivalents Fraction Decimal 1/ 64 0.015625 1/ 32 0.03125 3/ 64 0.046875 1/ 16 0.0625 5/ 64 0.078125 3/ 32 0.09375 7/ 64 0.109375 1/ 8 0.1250 9/ 64 0.140625 5/ 32 0.15625 11/ 0.171875 64 3/ 16 0.1875 13/ 0.203125 64 7/ 32 0.21875 15/ 0.234375 64 1/ 4 0.2500 17/ 0.265625 64 9/ 32 0.28125 19/ 0.296875 64 5/ 16 0.3125 21/ 0.328125 64 11/ 32 0.34375 23/ 0.359375 64 3/ 8 0.3750 25/ 0.390625 64 13/ 32 0.40625 mm Fraction 0.794 17/ 32 9/ 16 19/ 32 5/8 21/ 32 11/ 16 23/ 32 3/ 4 25/ 32 13/ 16 27/ 32 7/ 8 29/ 32 27/ 0.421875 10.716 64 7/ 16 0.4375 11.113 0.46875 11.906 15/ 16 0.5000 12.700 0.9375 61/ 64 0.953125 31/ 32 31/ 0.484375 12.303 64 1/ 2 0.90625 59/ 64 0.921875 29/ 0.453125 11.509 64 15/ 32 0.8750 57/ 64 0.890625 9.922 10.319 0.84375 55/ 64 0.859375 9.128 9.525 0.8125 53/ 64 0.828125 8.334 8.731 0.78125 51/ 64 0.796875 7.541 7.938 0.7500 49/ 64 0.765625 6.747 7.144 0.71875 47/ 64 0.734375 5.953 6.350 0.6875 45/ 64 0.703125 5.159 5.556 0.65625 43/ 64 0.671875 4.366 4.763 0.6250 41/ 64 0.640625 3.572 3.969 0.59375 39/ 64 0.609375 2.778 3.175 0.5625 37/ 64 0.578125 1.984 2.381 0.53125 35/ 64 0.546875 1.191 1.588 Decimal 33/ 64 0.515625 0.397 0.96875 63/ 64 0.984375 1 1 mm = 0.03937 inch 0.001 inch = 0.0254 mm 9 1.000 mm 13.097 13.494 13.891 14.288 14.684 15.081 15.478 15.875 16.272 16.669 17.066 17.463 17.859 18.256 18.653 19.050 19.447 19.844 20.241 20.638 21.034 21.431 21.828 22.225 22.622 23.019 23.416 23.813 24.209 24.606 25.003 25.400 Conversion of Customary Units to SI/Metric Units Basic Unit Customary Units (Abbreviation) SI/Metric Conversion Units Customary to (Abbreviation) SI/Metric Multiply by Length in mm 25.4 Area sq in mm2 645.16 Volume, capacity cu ft U.K. gal U.S. gal m3 L L 0.028317 4.546092 3.785412 Plane angle deg (0) rad Time min S Mass lbm kg Temperature (traditional) 0 0 Pressure lbf/in2(psi) N/m2 at (kp/cm2) bar bar Pa bar Pa 0.068947 1. 1.0197 105 Density (liquids) lbm/U.S. gal lbm/U.K. gal lbm/ft kg/m3 kg/m3 kg/m3 119.8264 99.77633 16.01846 Density (solids) lbm/ft3 kg/m3 16.01846 Throughput (mass basis) lbm/hr kg/h 0.453592 Throughput (volume basis) bbl/D ft3/D U.K. gal/min U.S. gal/min m3/h m3/h L/min L/min 0.006624 0.001179 4.546092 3.785412 Flow rate (volume basis) U.K. gal/min U.S. gal/min L/min L/min 4.546092 3.785412 ft3/min m3/min 0.028314 Energy work Btu ft-lbf lbf-ft K N-m kWh kJ kJ kJ 0.000293 0.001356 0.001356 1. Power hydraulic horse power-hhp hp (electric) Btu/hr kW 0.746043 kW W 0.746 0.293071 Fuel consumption mile/U.S. gal mile/U.K. gal km/L km/L 0.425144 0.354066 Velocity (linear) speed ft/min in/s m/s mm/s 0.005080 25.4 Rotational frequency rev/s rev/min rev/s rev/s 1.0 0.016666 F C 0.017453 60 0.453592 (0F-32) 1.8 Weight/length lb/ft kg/m 1.488164 Force lbf kg-m/sec2 N N 4.448222 1. Bending moment torque lbf-ft Nm Section modulus cu in mm3 Stress kgf/mm2 lbf/in2 (psi) N/mm2 N/mm2 10 1.355818 2831685 9.806650 0.006895 Drill Pipe with Double Shoulder Connections Box Hardbanding Pipe External Upset Tool Joint Elevator Shoulder Internal Upset Internal Coating Grant Prideco Double Shoulder Connection Primary Shoulder Provides seal and preload just as on conventional tool joint. Pin Base Pin base extends in spring-like manner when joint is bucked up to recommended make-up torque. Secondary Shoulder When joint is hand tight, secondary shoulders do not contact. When joint is bucked up to recommended make-up torque, they do contact. Box Counterbore Section Box counterbore section compresses in spring-like manner when joint is bucked up to recommended make-up torque. Pin Nose 11 DOUBLE SHOULDER CONNECTIONS Pin Weld Types of Grant Prideco Double Shoulder Connections There are three types of double shoulder connections offered by Grant Prideco. • HI TORQUE® (HT) – First generation double shoulder connection providing approximately 40% more torque capacity than API connections of equivalent dimensions. Not interchangeable with API connections. • eXtreme® Torque (XT® ) – Second generation double shoulder connection providing approximately 70% more torque capacity than API connections of equivalent dimensions. Not interchangeable with API connections. Two primary differences exist between HT and XT connections: 1) XT has a flatter taper and 2) XT has increased thread root radii. o eXtreme® Torque with Metal-To-Metal Seal (XTM™) – Industry first gas tight pressure rated rotary shoulder connection achieved through a 15° metalto-metal (M-T-M) seal on the pin nose. Provides torque capacity similar to that of XT connections. Not interchangeable with API connections. • Grant Prideco Double Shoulder™ (GPDS™) – Double shoulder connection which is interchangeable with API connections and provides 20-50% more torque capacity than API connections of equivalent dimensions. The below figure illustrates the taper difference between HT and XT connections. HT XT 12 HT Tool Joint Make-up Torque Chart Recommended Maximum Type Connection 2 3/8 HTSLH90 2 7/8 HTPAC HT26 HT31 HT38 HT40 HT46 HT50 HT55 HT65 Box OD (in) Pin ID (in) Make-up Torque (ft-lb) 3 3/8 3 1/8 3 1/8 3 1/8 3 1/4 3 3/16 3 1/8 3 5/8 3 5/8 3 5/8 3 1/2 3 3/8 4 1/4 4 1/8 4 1/8 4 1/8 4 1/8 4 5 5 5 4 15/16 4 7/8 4 7/8 4 3/4 4 3/4 4 3/4 5 1/4 5 1/8 5 1/8 5 5 6 1/4 6 1/4 6 5/8 6 5/8 6 5/8 6 5/8 6 1/2 7 3/8 7 1/4 7 1/4 7 1/4 7 1/4 7 1/4 7 1/4 7 1/8 7 1/8 7 1/8 7 7 7 7 7 8 1.815 1 7/16 1 3/4 1.975 1 1/2 1 1/2 1 1/2 1 1/4 1 3/8 1 1/2 1 1/2 1 3/4 1 3/4 1 7/8 2 2 1/8 2 5/32 2 5/32 2 5/16 2 7/16 2 9/16 2 9/16 2 7/16 2 9/16 2 7/16 2 9/16 2 11/16 2 13/16 2 9/16 2 11/16 2 7/16 2 9/16 3 3 1/4 3 3 1/4 3 1/2 3 3/4 3 1/2 4 3 3 1/4 3 1/2 3 3/4 3 7/8 4 3 1/4 3 7/8 4 3 3 1/4 3 1/2 3 3/4 4 5 6,300 6,800 5,600 4,600 5,200 5,100 5,100 9,200 8,700 7,900 7,300 5,200 14,000 11,900 11,300 10,000 9,600 8,900 21,700 19,800 17,700 17,700 19,300 17,700 17,000 16,100 15,200 19,200 21,100 20,100 19,600 18,600 34,600 28,500 53,300 46,800 39,700 32,000 39,600 46,800 72,000 69,000 63,900 55,600 51,200 46,700 64,200 51,100 46,500 62,500 59,500 56,300 52,600 46,300 59,800 Note: Applies to drill pipe and HWDP tool joints. 13 XT® Tool Joint Make-up Torque Chart Recommended Maximum Type Connection XT24 XT26 XT29 XT31 XT38 XT39 XT40 XT46 XT50 XT54 XT55 XT57 XT65 XT69 Box OD (in) Pin ID (in) XT Make-up Torque (ft-lb) 3 1/8 3 1/2 3 1/2 3 1/2 3 3/4 4 1/8 4 1/8 4 4 4 4 4 7/8 4 13/16 4 3/4 4 3/4 4 3/4 5 5 5 5 4 15/16 4 15/16 4 29/32 4 29/32 4 7/8 4 7/8 4 7/8 4 7/8 5 1/4 5 1/4 5 1/4 6 1/4 6 5/8 6 5/8 6 1/2 6 1/2 6 1/2 6 3/8 6 3/8 6 3/4 6 5/8 7 3/8 7 7 3/8 7 1/4 7 1/4 7 1/4 7 1/4 7 1/4 7 1/4 7 1/8 7 1/8 7 7 7 7 8 8 1/2 1 1/2 1 1/4 1 1/2 1 3/4 2 1 7/8 2 2 2 1/8 2 5/32 2 3/8 2 9/16 2 9/16 2 7/16 2 9/16 2 11/16 2 9/16 2 11/16 2 13/16 2 7/8 2 9/16 2 13/16 2 3/4 2 13/16 2 9/16 2 11/16 2 3/4 2 13/16 2 11/16 2 13/16 3 3 1/4 3 1/2 3 3/4 2 3/4 3 1/2 3 3/4 3 1/2 3 3/4 4 4 3 5/8 4 3 1/4 3 3/16 3 1/4 3 1/2 3 3/4 4 4 1/4 3 1/4 4 1/4 3 1/2 3 3/4 4 4 1/4 5 5 1/4 5,700 9,900 8,900 6,900 9,000 14,000 12,700 12,200 11,200 10,800 7,900 18,900 18,800 20,500 18,800 16,600 24,500 22,200 19,800 18,600 23,400 19,800 21,000 19,800 22,200 21,200 20,700 19,800 28,800 26,400 22,400 42,100 54,400 46,400 61,600 52,800 46,200 48,700 45,100 52,000 49,900 72,200 58,100 90,000 85,700 84,900 81,900 76,300 66,900 56,900 79,900 56,800 71,600 67,900 63,700 56,600 81,200 100,300 Note: Applies to drill pipe and HWDP tool joints. 14 XT-M™ Tool Joint Make-up Torque Chart Recommended Maximum Type Connection XT-M26 XT-M31 XT-M34 XT-M38 XT-M39 XT-M40 XT-M43 XT-M46 XT-M50 XT-M57 XT-M65 XT-M69 Box OD (in) Pin ID (in) XT-M Make-up Torque (ft-lb) 3 3/8 4 4 3 7/8 4 1/4 4 3/4 4 3/4 5 5 5 4 7/8 5 1/4 5 1/4 5 1/4 6 1/4 6 5/8 6 1/2 6 1/4 6 1/4 7 1/4 7 7 8 8 1/2 1 3/4 2 2 1/8 2 1/8 2 9/16 2 9/16 2 11/16 2 7/16 2 9/16 2 13/16 2 11/16 2 11/16 3 3 1/4 3 3 1/2 3 3/4 3 1/2 3 5/8 4 1/4 4 1/8 4 1/4 5 5 1/4 5,800 10,800 9,700 8,500 9,500 16,700 14,500 23,300 22,300 17,700 18,900 26,200 23,500 19,500 45,100 50,300 42,100 40,700 38,900 51,900 56,500 51,600 74,600 92,900 Note: Applies to drill pipe and HWDP tool joints. 15 GPDS™ Tool Joint Make-up Torque Chart Recommended Maximum Type Connection GPDS26 GPDS31 GPDS38 GPDS40 GPDS46 GPDS50 GPDS55 GPDS65 Box OD (in) Pin ID (in) Make-up Torque (ft-lb) 3 1/2 3 1/2 3 1/2 4 1/8 4 1/8 5 5 4 7/8 4 7/8 4 3/4 4 3/4 5 1/4 5 1/4 5 1/4 5 5 6 1/2 6 6 6 6 5/8 6 5/8 6 5/8 6 1/2 6 1/2 6 1/2 6 3/8 7 1/4 7 1/4 7 1/8 7 7 7 8 1/4 8 8 1 3/4 1 11/16 1 5/8 2 1 7/8 2 7/16 2 9/16 2 7/16 2 9/16 2 1/8 2 1/2 2 7/16 2 9/16 2 11/16 2 7/16 2 9/16 3 1/2 2 3/4 3 3 1/4 2 3/4 3 3 1/4 3 1/4 3 1/2 3 3/4 3 1/4 3 3/4 4 1/8 3 3/4 3 1/2 3 3/4 4 4 3/4 4 15/16 4 7/8 5,300 5,800 6,300 10,300 10,900 17,500 15,500 17,100 15,400 16,900 14,500 22,800 21,900 19,600 17,800 16,900 18,800 36,400 31,800 25,700 54,400 49,700 43,300 43,100 36,100 28,500 41,200 53,800 40,100 53,600 53,900 50,300 44,500 71,400 61,200 64,500 Note: Applies to drill pipe and HWDP tool joints. 16 The following sections provide general guidelines for running and handling double shoulder connections. Connection-specific running and handling procedures are available direct from Grant Prideco and can be downloaded from www.grantprideco.com. Tool Joint Break-in Most drill pipe connections are broken-in during manufacture. The following break-in procedure is recommended for connections which have not been broken-in during manufacture. Step 1: Make the joints up to the maximum recommended make-up torque, and then break them out. If the break-out torque is less than the make-up torque, the joints do not have to be separated. Step 2: Make the joints up again to the same make-up torque and break them out. Separate the pin and box and reapply thread compound. Step 3: Make the joints up again to the same makeup torque and they are ready for service. Note: The break-out torque should be less than the make-up torque. If the break-out torque is more than the make-up torque, separate the joints and inspect them for damage. Picking Up Pipe with Double Shoulder Connections for the First Time • Visually examine the thread protectors for damage such as dents or crushing. If any thread protectors are damaged, inspect the threads on that joint for damage. • If the joints were shipped to the rig with rust preventive on the threads, it must be removed. Use soap and water, steam or a vapor degreasing solvent such as Varsol. No residue should remain on the threads after cleaning. • If the joints were shipped to the rig with thread compound, it is not necessary to remove the thread compound unless there is a problem suspected. • Inspect the threads for damage or for foreign material. • Before the joints are put in service, the threads, the primary make-up shoulders and secondary make-up shoulders must be coated with a good quality rotary shouldered connection thread compound. 17 Special Considerations When Running XT® and XT-M™ Connections • Check to ensure the counterbalance on the top drive is working properly and provides a minimum amount of weight applied to the connection during make-up. • Ensure the bore through the top drive bell stabbing guide (top drive flipper) is no more than 1/2" larger in diameter than the box tool joint diameter. • Because of the flatter taper, XT and XT-M pins do not stab as deeply into the box as do HT, GPDS™ and API connections. Alignment of the pin to the box when stabbing and spinning up is more critical for XT and XT-M connections. A stabbing guide is required when running XT and XT-M connections, and alignment should be verified before spinning up. • Proper alignment, along with slow initial make-up of the starting threads, is necessary with XT and XT-M connections. Use chain tongs or slow speed spinners when spinning in the starting threads. Highspeed spinners may be used after the starting threads are engaged. • Minor thread damage may occur within the starting threads. This is not detrimental to the connection and should be removed with a soft grinding wheel or a file. 18 Application of Thread Compound to Double Shoulder Connections • All contacting surfaces, the threads, the primary shoulders, secondary shoulders and 15° M-T-M seal (XT-M™), must be coated with a good quality rotary shoulder connection thread compound. Copperbased thread compounds are recommended. • Some drilling fluids or drilling fluid additives may affect the frictional properties of the tool joint and thread compound. If this is the case, rinse the drilling fluid off the connections before applying thread compound. • Remove drilling fluid from the secondary shoulder and 15° M-T-M seal (XT-M) of the box before making up the connection for the trip in the hole. Trapped drilling fluid can promote corrosion of the secondary shoulders. • Racking the pipe will wipe thread compound off the pin nose. If pins are doped coming out of the hole, reapply compound to the secondary shoulder before the connections are made up. • NOTE: For XT-M connections, localized corrosion or pitting may occur on the 15° M-T-M seal if racked back without thread compound applied to it. This is more common with completion fluids than common drilling fluids. Apply a liberal and even coat of quality thread compound to the 15° seal when racking back XT-M connections. Primary Shoulder Threads Secondary Shoulder 15° M-T-M Seal 19 Tonging, Proper Gripping of the Box During Make-up • Tongs should be placed at least 2 inches from the make-up shoulder on XT® boxes size 46 and greater, all HT and all XT-M™ boxes. These are considered "long" double shoulder connections. This is not required for XT boxes less than 46 and all GPDS™ boxes. • The threads of a long double shoulder box are about 1-1/2 inches further away from the makeup shoulder than the threads of an API box. Tongs or top drive torque wrenches should engage these long double shoulder boxes at the same location in relation to the threads that they would engage an API joint. • On the Varco BJ® PH85 pipe handler torque wrench, this can be accomplished by decreasing the length of the saver sub from 7 inches to 5-1/2 inches. This will put the tong dies 2 inches from the box make-up shoulder. • Back-up tongs should always be used 2 inches Recommended Tonging Area 20 Tong Height • Bucking up tool joints with tongs can put high bending loads in the pipe. • Review the IADC Drilling Manual Latest Edition, or Tong Height Figure in API RP 7G Latest Edition about height of tool joint above slips to prevent bending pipe during tonging. P H max P 21 Alignment when Making up Connections • Galling and other damage can occur during stabbing and spinning connections up. • A stand of pipe can weigh between 1,500 lbs and 2,300 lbs. At initial contact, the weight could be supported by the sharp edge of one thread against the flank of the mating thread. This can cause high contact stresses and wipe the thread compound off. • Slight misalignment of the pin and box can cause further increases in the stresses when spinning up. • The “whipping” action of spinning pipe can cause high loads on threads. • NOTE: Alignment of the pin to the box when stabbing and spinning up is more critical for XT® and XT-M™ connections. A stabbing guide is required when running XT and XT-M connections and alignment should be verified before spinning up. Box Pin Contact of sharp edge of pin thread on box flank Tripping • Alternate breaks when tripping so that each joint will be broken-out every third trip. • Monitor break-out torque. • The break-out torque should be less than the makeup torque. High break-out torque is an indication of downhole make-up or thread damage. • Do not let the end of the pin strike the box make-up shoulder when stabbing the pin in the box. Stabbing guides are required for XT and XT-M connections and recommended for HT and GPDS™ connections. 22 Standing Pipe Back • Using normal drill pipe care and handling practices, no special care is required to protect the pin nose when standing the pipe back. The pin nose is not a seal. Minor damage to the pin nose from standing the pipe back does not affect the connection’s performance. • It is not necessary to use thread protectors when standing the pipe back. • Do not use pressed steel thread protectors when standing the pipe back. They could allow the weight of the stand to be supported by the primary make-up shoulder of the connection on the sharp edge of the thread protectors. • Apply a liberal and even coat of quality thread compound to the 15° M-T-M seal when racking back XT-M™ connections. Sharp edge of thread protector can damage shoulder. 23 Downhole Make-up • Downhole make-up can be detected by high breakout torque. The break-out torque should be less than the make-up torque. • If downhole make-up is suspected, punch mark the pin and box next to the make-up shoulders when tripping into the hole (after the connection is made up). • If downhole make-up occurs, the position of the punch marks will change. • Downhole make-up can cause — Compressed box counterbores — Compressed pin noses Milled Hardness Flat Punch marks Apply punch marks in line with hardness flat to make them easier to find. 24 The following sections provide information and general guidelines regarding the field inspection of Grant Prideco double shoulder connections and are not intended to replace Grant Prideco Field Inspection Procedures and Drawings. Connection type-specific Field Inspection Procedures and connection type and size-specific Field Inspection Drawings are available direct from Grant Prideco and can be downloaded from www.grantprideco.com. Make-up Shoulder and Bevel Diameter • The primary make-up shoulders provide the seal for the connection (HT, XT® and GPDS™). For XT-M™, the primary seal is the 15° M-T-M seal and the backup seal is the primary make-up shoulder. • The primary make-up shoulders and 15° M-T-M seal (XT-M) should be inspected frequently using current Grant Prideco Field Inspection Procedures for the applicable connection type. • Proper operation and correct shoulder loads depend on the pin length and box depth of double shoulder connections being within specifications. The pin length and box depth are shown on the Field Inspection Drawing for the particular size and type connection. • No more than 1/32 inch should be removed from either the primary or secondary make-up shoulder at any one refacing. No more than 1/16 inch cumulatively should be removed from either the primary or secondary make-up shoulder. The correct pin length and box depth must be maintained when resurfacing make-up shoulders. • The Grant Prideco benchmark is a reference for checking how much material has been removed from make-up shoulders. • The surface finish of the primary make-up shoulder should be 150 RMS or less. • When Grant Prideco double shoulder connections are refaced, the bevel does not need to be remachined. 25 • The pin nose is not a seal, it is a mechanical stop. The pin nose must be free of raised metal or other imperfections that could prevent proper make up or cause galling. Pin nose damage can be repaired with a hand file. 1 3 2 Pin 1 2 3 Box 1 3 2 1 26 2 3 Checking Pin Length • The pin length can be checked with a dial indicator or depth micrometers. If the pin length is short by 1/32 inch or less, the pin can be repaired by resurfacing the primary shoulder. • If the pin length is short by more than 1/32 inch, the pin must be recut. • If the pin length is too long by 1/32 inch or less, the pin can be repaired by resurfacing the pin nose. • If the pin length is too long by more than1/32 inch, the pin must be recut. A Go/No Go gauge can be provided by Grant Prideco to field check double shoulder connections’ primary shoulder to secondary shoulder pin length and box depth. The gauge does not provide dimensional information on the pin length or box depth. If the pin nose does not contact the gauge when used as shown in the figure, the length should be inspected with measuring instruments that determine the actual distance between the shoulders. 27 Checking Box Depth • The box depth can be checked with a dial indicator or depth micrometers. If the box depth is short by 1/32 inch or less, the box can be repaired by resurfacing the secondary shoulder. • If the box depth is short by more than 1/32 inch, the box must be recut. • If the box depth is too long by 1/32 inch or less, the box can be repaired by resurfacing the primary shoulder. • If the box depth is too long by more than 1/32 inch, the box must be recut. A Go/No Go gauge can be provided by Grant Prideco to field check double shoulder connections’ primary shoulder to secondary shoulder pin length and box depth. The gauge does not provide dimensional information on the pin length or box depth. If the primary shoulder does not contact the gauge when used as shown in the figure, the depth should be inspected with measuring instruments that determine the actual distance between the shoulders. 28 Special Considerations When Inspecting XT® and XT-M™ Connections • The stab flank to crest radius of the starting four to five threads of the pin and box connections round off during break-in and normal operation. Minor thread damage may occur within these starting threads. This is not detrimental to the connection and should be removed with a soft grinding wheel or a file. • The XT-M connection contains a 15° M-T-M seal near the pin and box secondary shoulders. This is the primary sealing surface for the connection. o Round pit type defects up to 1/32 inch in diameter and not exceeding 1/32 inch in depth are permissible. o Multiple pits of this type are acceptable provided there is at least 1 inch circumferential separation between them. o Circumferential lines or marks are acceptable provided they cannot be detected by rubbing a fingernail across the surface. o Areas highlighted in the figure below are the non-contacting areas of the seal. Damage or pitting is permitted in these areas of the seal, provided the balance of the contact surface is without damage exceeding the requirements above. o XT-M connections may not be refaced. Damages exceeding requirements for the threads, seal and/or shoulder faces require the connection to be faced/chased. Box Seal 0.188 0.060 0.060 Pin Seal 29 30 Thread Form Pin Cylinder Dia Pin Length Nose Dia Bevel Dia Field Inspection Drawing, Pin Thread Form 90°V 084 V 076S V 038R V 038R V 038R V 038R V 038R V 038R V 050 V 050 Connection 2 3/8 HTSLH90 2 7/8 HTPAC HT26 HT31 HT38 HT40 HT46 HT50 HT55 HT65 Pin Length (in) 4.429 - 4.438 4.821 - 4.830 5.156 - 5.165 5.334 - 5.343 5.496 - 5.505 6.267 - 6.276 6.282 - 6.291 6.150 - 6.159 7.338 - 7.347 7.491 - 7.500 Bevel Dia (in) 2.984 - 3.141 3.047 - 3.204 3.296 - 3.453 3.937 - 4.094 4.637 - 4.794 4.859 - 5.016 5.829 - 5.986 6.124 - 6.281 6.857 - 7.014 7.547 - 7.704 Pin Cylinder Dia (in) 2.607 - 2.653 2.406 - 2.452 2.719 - 2.765 3.360 - 3.406 3.880 - 3.926 4.125 - 4.171 4.678 - 4.724 5.094 - 5.140 5.689 - 5.735 6.616 - 6.662 Nose Dia (in) 2.216 - 2.263 1.967 - 2.014 2.109 - 2.156 2.574 - 2.621 3.172 - 3.219 3.306 - 3.353 3.859 - 3.906 4.297 - 4.344 4.666 - 4.713 5.566 - 5.613 HT Field Inspection Dimensions, Pin 31 Thread Form V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R Connection XT24 XT26 XT29 XT30 XT31 XT34 XT38 XT39 XT40 XT43 XT46 XT50 XT54 XT55 XT57 XT61 XT65 XT69 Pin Length (in) 3.210 - 3.219 3.116 - 3.125 3.647 - 3.656 3.366 - 3.375 3.991 - 4.000 4.147 - 4.156 4.616 - 4.625 4.491 - 4.500 4.491 - 4.500 3.647 - 3.656 7.491 - 7.500 7.291 - 7.300 6.991 - 7.000 7.241 - 7.250 7.241 - 7.250 6.241 - 6.250 8.241 - 8.250 7.804 - 7.813 Bevel Dia (in) 2.984 - 3.141 3.203 - 3.360 3.578 - 3.735 3.703 - 3.860 3.859 - 4.016 4.109 - 4.266 4.547 - 4.704 4.770 - 4.927 5.000 - 5.157 5.047 - 5.204 5.918 - 6.075 6.302 - 6.459 6.453 - 6.610 6.857 - 7.014 6.705 - 6.862 6.961 - 7.118 7.703 - 7.860 7.797 - 7.954 Pin Cylinder Dia (in) 2.490 - 2.536 2.728 - 2.774 3.029 - 3.075 3.174 - 3.220 3.235 - 3.281 3.535 - 3.581 3.844 - 3.890 4.026 - 4.072 4.234 - 4.280 4.385 - 4.431 4.920 - 4.966 5.306 - 5.352 5.564 - 5.610 5.680 - 5.726 5.806 - 5.852 6.213 - 6.259 6.681 - 6.727 7.056 - 7.102 Nose Dia (in) 2.067 - 2.114 2.309 - 2.356 2.589 - 2.636 2.740 - 2.787 2.740 - 2.787 3.063 - 3.110 3.332 - 3.378 3.531 - 3.578 3.735 - 3.782 3.927 - 3.974 4.321 - 4.368 4.743 - 4.790 5.020 - 5.067 5.101 - 5.148 5.262 - 5.309 5.530 - 5.577 6.074 - 6.121 6.476 - 6.523 XT® Field Inspection Dimensions, Pin 32 Thread Form V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R Connection XT-M24 XT-M26 XT-M29 XT-M31 XT-M34 XT-M38 XT-M39 XT-M40 XT-M43 XT-M46 XT-M50 XT-M57 XT-M61 XT-M65 XT-M69 Pin Length (in) 5.054 - 5.063 4.991 - 5.000 5.491 - 5.500 5.866 - 5.875 5.991 - 6.000 6.491 - 6.500 6.241 - 6.250 6.491 - 6.500 5.616 - 5.625 7.491 - 7.500 7.291 - 7.300 7.241 - 7.250 6.241 - 6.250 8.241 - 8.250 7.804 - 7.813 Bevel Dia (in) 2.984 - 3.141 3.203 - 3.360 3.578 - 3.735 3.859 - 4.016 4.078 - 4.235 4.547 - 4.704 4.770 - 4.927 5.000 - 5.157 5.047 - 5.204 5.918 - 6.075 6.302 - 6.459 6.705 - 6.862 6.961 - 7.118 7.703 - 7.860 7.797 - 7.954 Pin Cylinder Dia (in) 2.490 - 2.536 2.728 - 2.774 3.029 - 3.075 3.235 - 3.281 3.535 - 3.581 3.844 - 3.890 4.026 - 4.072 4.234 - 4.280 4.385 - 4.431 4.920 - 4.966 5.306 - 5.352 5.806 - 5.852 6.213 - 6.259 6.681 - 6.727 7.056 - 7.102 Nose Dia (in) NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA XT-M™ Field Inspection Dimensions, Pin 33 Thread Form V 038R V 038R V 038R V 038R V 038R V 038R V 050 V050 Connection GPDS26 GPDS31 GPDS38 GPDS40 GPDS46 GPDS50 GPDS55 GPDS65 Pin Length (in) 3.372 - 3.382 3.884 - 3.894 4.396 - 4.406 4.907 - 4.918 4.907 - 4.918 4.907 - 4.918 5.419 - 5.430 5.419 - 5.430 Bevel Dia (in) 3.250 - 3.407 3.937 - 4.094 4.562 - 4.719 5.000 - 5.157 5.703 - 5.860 6.047 - 6.204 6.703 - 6.860 7.687 - 7.844 Pin Cylinder Dia (in) 2.719 - 2.765 3.235 - 3.281 3.860 - 3.906 4.125 - 4.171 4.678 - 4.724 5.104 - 5.150 5.688 - 5.734 6.616 - 6.620 Nose Dia (in) 1.985 - 2.031 2.423 - 2.469 2.954 - 3.000 3.141 - 3.187 3.688 - 3.734 4.110 - 4.156 4.548 - 4.594 5.469 - 5.515 GPDS™ Field Inspection Dimensions, Pin 34 Box Depth C Bore Dia 35 C Bore Wall Bevel Dia Field Inspection Drawing, Box Thread Form 90°V 084 V 076S V 038R V 038R V 038R V 038R V 038R V 038R V 050 V050 Connection 2 3/8 HTSLH90 2 7/8 HTPAC HT26 HT31 HT38 HT40 HT46 HT50 HT55 HT65 Box Depth (in) 4.443 - 4.448 4.835 - 4.840 5.168 - 5.173 5.351 - 5.356 5.510 - 5.515 6.281 - 6.286 6.296 - 6.301 6.164 - 6.169 7.352 - 7.357 7.504 - 7.509 Bevel Dia (in) 2.984 - 3.141 3.047 - 3.204 3.296 - 3.453 3.937 - 4.094 4.637 - 4.794 4.859 - 5.016 5.829 - 5.986 6.124 - 6.281 6.857 - 7.014 7.547 - 7.704 Counter bore Dia (in) 2.727 - 2.789 2.539 - 2.601 2.907 - 2.969 3.422 - 3.484 4.047 - 4.109 4.313 - 4.375 4.875 - 4.937 5.282 - 5.344 5.875 - 5.937 6.813 - 6.875 Minimum CBore Wall (in) 0.094 0.188 0.188 0.188 0.313 0.313 0.313 0.313 0.313 0.313 HT Field Inspection Dimensions, Box 36 Thread Form V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R Connection XT24 XT26 XT29 XT30 XT31 XT34 XT38 XT39 XT40 XT43 XT46 XT50 XT54 XT55 XT57 XT61 XT65 XT69 Box Depth (in) 3.217 - 3.222 3.123 - 3.128 3.654 - 3.659 3.373 - 3.378 3.998 - 4.003 4.154 - 4.159 4.623 - 4.628 4.498 - 4.503 4.498 - 4.503 3.654 - 3.659 7.505 - 7.510 7.305 - 7.310 7.005 - 7.010 7.255 - 7.260 7.255 - 7.260 6.255 - 6.260 8.255 - 8.260 7.818 - 7.823 Bevel Dia (in) 2.984 - 3.141 3.203 - 3.360 3.578 - 3.735 3.703 - 3.860 3.859 - 4.016 4.109 - 4.266 4.547 - 4.704 4.770 - 4.927 5.000 - 5.157 5.047 - 5.204 5.918 - 6.075 6.302 - 6.459 6.453 - 6.610 6.857 - 7.014 6.705 - 6.862 6.961 - 7.118 7.703 - 7.860 7.767 - 7.954 Counter bore Dia (in) 2.593 - 2.655 2.831 - 2.893 3.132 - 3.194 3.267 - 3.329 3.342 - 3.404 3.638 - 3.700 3.947 - 4.009 4.121 - 4.183 4.324 - 4.386 4.488 - 4.550 5.071 - 5.133 5.409 - 5.471 5.667 - 5.729 5.783 - 5.845 5.909 - 5.971 6.316 - 6.378 6.784 - 6.846 7.159 - 7.221 Minimum CBore Wall (in) 0.188 0.188 0.188 0.188 0.188 0.188 0.250 0.250 0.250 0.313 0.313 0.313 0.313 0.313 0.313 0.313 0.313 0.313 XT® Field Inspection Dimensions, Box 37 Thread Form V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R V 042R Connection XT-M24 XT-M26 XT-M29 XT-M31 XT-M34 XT-M38 XT-M39 XT-M40 XT-M43 XT-M46 XT-M50 XT-M57 XT-M61 XT-M65 XT-M69 Box Depth (in) 5.068 - 5.073 5.005 - 5.010 5.505 - 5.510 5.880 - 5.885 6.005 - 6.010 6.505 - 6.510 6.255 - 6.260 6.505 - 6.510 5.630 - 5.635 7.505 - 7.510 7.305 - 7.310 7.255 - 7.260 6.255 - 6.260 8.255 - 8.260 7.818 - 7.823 Bevel Dia (in) 2.984 - 3.141 3.203 - 3.360 3.578 - 3.735 3.859 - 4.016 4.078 - 4.235 4.547 - 4.704 4.770 - 4.927 5.000 - 5.157 5.047 - 5.204 5.918 - 6.075 6.302 - 6.459 6.705 - 6.862 6.961 - 7.118 7.703 - 7.860 7.797 - 7.954 Counter bore Dia (in) 2.593 - 2.655 2.831 - 2.893 3.132 - 3.194 3.342 - 3.404 3.638 - 3.700 3.947 - 4.009 4.129 - 4.191 4.324 - 4.386 4.488 - 4.550 5.071 - 5.133 5.409 - 5.471 5.909 - 5.971 6.316 - 6.378 6.784 - 6.846 7.159 - 7.221 Minimum CBore Wall (in) 0.188 0.188 0.188 0.188 0.250 0.250 0.250 0.250 0.313 0.313 0.313 0.313 0.313 0.313 0.313 XT-M™ Field Inspection Dimensions, Box 38 Thread Form V 038R V 038R V 038R V 038R V 038R V 038R V 050 V050 Connection GPDS26 GPDS31 GPDS38 GPDS40 GPDS46 GPDS50 GPDS55 GPDS65 Box Depth (in) 3.380 - 3.391 3.892 - 3.903 4.404 - 4.415 4.915 - 4.927 4.915 - 4.927 4.915 - 4.927 5.427 - 5.439 5.427 - 5.439 Bevel Dia (in) 3.250 - 3.407 3.937 - 4.094 4.562 - 4.719 5.000 - 5.157 5.703 - 5.860 6.047 - 6.204 6.703 - 6.860 7.687 - 7.844 Counter bore Dia (in) 2.899 - 2.961 3.414 - 3.476 4.039 - 4.101 4.305 - 4.367 4.867 - 4.929 5.274 - 5.336 5.867 - 5.929 6.805 - 6.867 Minimum CBore Wall (in) 0.188 0.188 0.250 0.250 0.313 0.313 0.313 0.313 GPDS™ Field Inspection Dimensions, Box 39 40 Heavy Weight Drill Pipe · Conventional HWDP – Developed to provide a gradual transition from the heavy drill collar to the relatively lightweight drill pipe. Conventional Heavy Weight Drill Pipe 180 24” B Elevator Upset Diameter C Wear Section Upset Diameter 26” 31’ Nominal Length A Nominal Size B Upset Diameter D Tool Joint OD 180 41 24” HEAVY WEIGHT DRILL PIPE Heavy weight drill pipe (HWDP) was developed to provide a gradual transition from heavy drill collars to relatively lightweight drill pipe. By providing a gradual change in weight and rigidity, HWDP reduces connection fatigue problems and increases drill stem service life. And because it bends more easily than drill collars, it simplifies directional control in highangle and horizontal drilling. HWDP has less wall contact than drill collars, reducing differential sticking tendencies. Spiraled HWDP configurations further decrease differential sticking tendency while helping to remove cuttings out of the annulus. Grant Prideco offers three types of HWDP configurations to meet the challenge of severe drilling conditions. Heavy Weight Drill Pipe · Tri-Spiral™ HWDP – Developed for high-angle applications such as extended reach and horizontal drilling. - Equally spaced, three spiral upset design helps improve cuttings removal, reduce differential sticking tendencies and torque and drag. Tri-Spiral Heavy Weight Drill Pipe D Box Tool Joint 24” B Elevator Upset Diameter C Spiral Upset 26” 31’ Nominal Length C Center Spiral Upset 26” C Spiral Upset 26” A Nominal Size B Upset Diameter D Pin Tool Joint 24” 42 Heavy Weight Drill Pipe · Spiral-Wate® HWDP – Designed to handle maximum stress to save time and reduce drilling costs, especially in tough drilling environments. - Unique patented spiral design reduces differential sticking problems, minimizes wear and improves circulation. Features more weight per joint and better hole cleaning characteristics than standard HWDP. Spiral-Wate Heavy Weight Drill Pipe D Box Tool Joint 24” B Elevator Upset Diameter 42” 31’ Nominal Length C Spiral Upset 21’4” A Nominal Size 11” D Pin Tool Joint 24” 43 44 1.063 0.938 1.125 1.000 0.875 0.719 0.625 0.719 0.688 Wall Thickness (in) 18.574 14.542 15.463 12.566 9.965 7.411 5.645 6.282 4.727 Area (in2) 22.476 15.630 14.342 10.681 7.698 5.225 3.490 3.702 2.161 6 7 1/8 6 3/8 5 1/ 2 5 4 1/2 4 4 3 5/16 Cen. S Upset Section Dia. Modulus [C] (in3) (in) 6 5/16 6 5 11/16 5 1/ 8 4 11/16 4 3/16 3 7/8 3 7/8 2 15/16 End Upset Dia. [B] (in) NOTE: 2 7/8” HWDP is manufactured integral only (non-welded). 4 4 5 7/8 6 3 1/4 5 1/2 1/ 2 3 5 5/ 8 2 3/4 4 1/2 3 1/2 2 9/16 2 1/4 3 1/2 4 1 1/2 2 1/16 2 7/8 ID (in) Nominal Size (in) Nominal Tube Dimensions Tube 1,021,600 799,800 850,400 691,200 548,100 407,600 310,500 345,400 520,000 Tensile Yield (lb) 118,900 82,700 75,900 56,500 40,700 27,600 18,500 19,600 22,400 Torsional Yield (ft-lb) Mechanical Properties Tube 6 5/8 FH XT57 5 1/2 FH HT55 NC50 (4 IF) HT50 1/ 2 NC46 (4 IF) NC40 (4 FH) XT39 8 7 7 1/4 6 5/ 8 6 1/4 5 4 1/ 4 7/ 8 3/ 4 7/ 8 7/ 8 NC38 (3 1/2 IF) HT38 XT39 4 4 4 4 3/4 3 3/8 OD [D] (in) 4 1/2 4 3 1/4 3 2 13/16 2 9/16 2 1/4 2 1/8 1 1/2 ID (in) Tool Joint NC38 (3 1/2 IF) NC26 (2 3/8 IF) Connection Size and Type Conventional Heavy Weight Drill Pipe 1,896,100 1,403,100 1,778,300 1,416,200 1,151,100 838,300 729,700 790,900 790,900 871,400 842,400 357,700 Tensile Yield (lb) 87,900 106,200 78,700 115,100 57,800 88,800 43,600 27,800 37,000 19,200 34,200 40,700 19,200 6,300 Torsional Yield (ft-lb) Mechanical Properties Tool Joint 71.43 57.42 61.63 50.38 41.45 29.92 28.40 23.48 23.96 23.96 25.65 17.26 Per foot 2,214 1,780 1,911 1,562 1,285 928 880 728 743 743 795 535 Per Joint (31 ft) Approx. Incl. Tube & Tool Joints Weight (lb) 50,500 63,700 41,200 69,000 30,000 53,300 22,500 14,600 22,200 11,500 20,500 24,400 11,500 3,800 Make-up Torque (ft-lb) Dimensional Data - Range II 45 2 3/4 3 3 1/4 4 4 1/2 4 1/2 5 5 1/2 5 7/8 6 5/8 NOTE: 2 7/8” Tri-Spiral TM 18.574 14.542 15.463 12.566 9.965 7.411 5.645 6.282 4.727 22.476 15.630 14.342 10.681 7.698 5.225 3.490 3.702 2.161 S Section Area Modulus (in2) (in3) 6 3/8 7 1/8 6 5/16 6 5 11/16 5 1/8 6 4 11/16 5 4 3/16 3 7/8 3 7/8 2 15/16 End Upset Dia. [B] (in) 5 1/2 4 1/2 4 4 3 5/16 Cen. Upset Dia. [C] (in) 799,800 850,400 691,200 548,100 407,600 310,500 345,400 520,000 Tensile Yield (lb) 118,900 82,700 75,900 56,500 40,700 27,600 18,500 19,580 22,400 Torsional Yield (ft-lb) Mechanical Properties Tube 6 5/8 FH XT57 5 1/2 FH HT55 NC50 (4 1/2 IF) HT50 NC46 (4 IF) NC40 (4 FH) XT39 NC38 (3 1/2 IF) HT38 XT39 NC38 (3 1/2 IF) NC26 (2 3/8 IF) Connection Size and Type 8 7 7 1/4 6 5/8 6 1/4 5 1/4 4 7/8 4 3/4 4 7/8 4 7/8 4 3/4 3 3/8 OD [D] (in) Tool Joint Tri-SpiralTM Heavy Weight Drill Pipe 1,021,600 is manufactured integral only (non-welded). 1.063 0.938 1.125 1.000 0.875 0.719 2 9/16 4 0.719 0.688 0.625 3 1/2 2 1/4 1 1/2 2 1/16 2 7/8 Wall Thickness (in) 3 1/2 ID (in) Nominal Size (in) Nominal Tube Dimensions Tube 4 1/2 4 3 1/4 3 2 13/16 2 9/16 2 1/4 2 1/8 1 1/2 ID (in) 1,896,100 1,403,100 1,778,300 1,416,200 1,151,100 838,300 729,700 790,900 790,900 871,400 842,400 357,700 Tensile Yield (lb) 87,900 106,200 78,700 115,100 57,800 88,800 43,600 27,800 37,000 19,200 34,200 40,700 19,200 6,300 Torsional Yield (ft-lb) Mechanical Properties Tool Joint 74.67 57.42 63.78 52.34 43.31 31.51 29.99 24.88 25.36 25.36 27.05 18.22 Per foot 2,315 1,780 1,977 1,623 1,343 977 930 771 786 786 839 565 Per Joint (31 ft) Approx. Incl. Tube & Tool Joints Weight (lb) 50,500 63,700 41,200 69,000 30,000 53,300 22,500 14,600 22,200 11,500 20,500 24,400 11,500 3,800 Make-up Torque (ft-lb) Dimensional Data - Range II 46 3 4 4 5 5 5 1/2 5 7/8 6 5/8 0.813 0.938 0.750 1.000 0.875 0.719 0.625 0.594 Wall Thickness (in) 14.837 14.542 11,192 12.566 9.965 7.411 5.645 4.840 19.285 15.630 11.764 10.681 7.698 5.225 3.490 2.687 S Section Area Modulus (in2) (in3) 7 1/8 6 3/8 6 3/4 6 5 5/8 5 1/8 6 4 5/8 5 4 1/8 3 5/8 3 3/16 End Upset Dia. [B] (in) 5 1/2 4 1/2 4 3 5/16 Cen. Upset Dia. [C] (in) 816,000 799,800 615,600 691,200 548,100 407,600 310,500 532,400 Tensile Yield (lb) 102,000 82,700 62,200 56,500 40,700 27,600 18,500 28,400 Torsional Yield (ft-lb) Mechanical Properties Tube 6 5/8 FH XT57 5 1/2 FH HT55 NC50 (4 1/2 IF) HT50 NC46 (4 IF) NC40 (4 FH) XT39 NC38 (3 1/2 IF) HT38 XT39 SLH90 Connection Size and Type 8 7 7 6 5/8 6 1/4 5 4 7/8 3 7/8 OD [D] (in) Tool Joint Spiral-Wate® Heavy Weight Drill Pipe NOTE: 3 3/16” Spiral-WateTM, previously referred to as 2-7/8”, is manufactured integral only (non-welded). 2 3/4 4 1/2 3 1/2 2 9/16 2 2 1/4 3 3/16 4 ID (in) Nominal Size (in) Nominal Tube Dimensions Tube 5 4 4 3 2 13/16 2 9/16 2 1/4 2 ID (in) 1,448,400 1,403,100 1,265,800 1,416,200 1,151,100 838,300 729,700 790,900 790,900 871,400 407,000 Tensile Yield (lb) 73,700 106,200 55,900 77,200 57,800 88,800 43,600 20,900 40,800 22,900 34,200 40,700 12,000 Torsional Yield (ft-lb) Mechanical Properties Tool Joint 73.40 65.38 55.21 59.16 49.53 28.90 30.39 19.48 Per foot 2,,275 2,027 1,712 1,834 1,535 896 942 604 Per Joint (31 ft) Approx. Incl. Tube & Tool Joints Weight (lb) 38,400 63,700 29,200 46,300 30,000 53,300 22,500 12,600 24,500 13,100 20,500 24,400 6,300 Make-up Torque (ft-lb) Dimensional Data - Range II Drill Collars Care And Maintenance Initial Make Up Even though quality connections are heavily coated with phosphate, thread damage is not always prevented. A generous and thorough application of highquality thread dope (40 to 60 percent metallic zinc minimum) will help prevent galling. New connections should be “walked in” with chain tongs. Always use the recommended make-up torque for the thread design. Exercise care to maintain calibrated torque measuring and indicating gauges for future use. After initial make-up, break-out the connection, visually inspect, redope and make-up two more times before running in the hole. Note: Monitor break-out torque, it should be less than or no greater than make-up torque. If it is greater, the connection should be cleaned, inspected and repaired, before it is made up again. Use thread protectors on both connections when handling drill collars. Alternate different joints on each trip. Clean and inspect the individual connections. Qualified personnel should periodically conduct a magnetic particle/black light inspection. Collars that are left idle or put in storage, should be cleaned, inspected, repaired and rust-proofed, as necessary before installing thread protectors. Field Welding Extreme caution should be used when welding drill collar material in the field. This material is high alloy steel, carefully heat-treated to provide optimum performance. When repair welding or hardbanding, use proper preheat, interpass and post-heat temperatures to prevent cracking and metallurgical degradation of the collar. Your Grant Prideco authorized repair facility can provide welding repair service to factory specifications to ensure weld area integrity. Contact your representative today for more information. 47 DRILL COLLARS Maintenance Care And Maintenance Bending Strength Ratios Sizes below six inches should have a BSR of 2.25:1 to 2.75:1. Conditions which require high rpm and small collars compared to the hole size, use 2.25:1 to 2.85:1. For abrasive conditions, use 2.50:1 to 3.00:1. If the rpm is kept low and the collars are closer to the hole size, use 2.25:1 to 3.20:1. In corrosive environments, use 2.50:1 to 3.00:1. Slip and Elevator Recesses 20” A A R Cold Work Shoulder Area 16” B B 2” Radius 3” 3” 1” Radius Shoulder Area C 2” Radius C 18” 3” 48 Materials Mechanical Properties Drill Collar Diameter (in) Min. Yield Strength (psi) Min. Tensile Strength (psi) Min. Hardness (BHN) 31/8 thru 67/8 110,000 140,000 285 7 thru 11 100,000 135,000 285 Slip and Elevator Recess Dimensions Drill Collar Diameter Elevator Recess Diameter Slip Recess Diameter Elevator Recess Radius A (in) B (in) C (in) R (in) 4 1/8 3 4 3/4 11/ 16 3 3/4 1/ 8 4 1/4 4 3/8 1/ 8 5 4 1/2 4 5/8 1/ 8 6 5 3/8 5 1/2 1/ 8 6 1/4 5 5/8 5 3/4 1/ 8 6 1/2 5 7/8 6 1/ 8 7 1/4 6 1/2 6 3/4 3/ 16 7 3/4 7 7 1/4 3/ 16 8 7 1/4 7 1/2 3/ 16 8 1/4 7 1/2 7 3/4 3/ 16 9 8 1/8 8 1/2 1/ 4 9 1/2 8 5/8 9 1/ 4 9 3/4 8 7/8 9 1/4 1/ 4 10 9 1/8 91/2 1/ 4 11 10 1/8 10 1/2 1/ 4 49 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Connection Size API 2 7/8 Type NC 23 3 PAC Bore of Drill Collar (in) 1 1/4 1 1/2 *2,500 *3390 *2,500 *3390 *2,500 *3390 3 1/8 *3,300 *4474 *3,300 *4474 2,600 3525 3 1/4 4,000 5423 3,400 *4610 2,600 3525 3 *3,800 *5152 *3,800 *5152 3 1/8 *4,900 6644 4,200 5694 31/4 5,200 7050 4,200 5694 OD (in) 3 1 2 3/8 API IF or 3 1/2 *4,600 *6237 *4,600 *6237 API NC 26 or 3 3/4 5,500 7457 4,700 6372 2 3/ 8 Slim Hole 2 7/8 Extra Hole or 3 3/4 *4,100 *5559 *4,100 *5559 3 1/2 Dbl. Streamline or 3 7/8 *5,300 *7186 *5,300 *7186 2 7/8 Mod. Open 4 1/8 *8,000 *10847 *8,000 *10847 2 7/8 API IF or 3 7/8 *4,600 *6237 *4,600 *6237 API NC 31 or 4 1/8 *7,300 *9897 *7,300 *9897 4 1/4 *8,800 *11931 *8,800 *11931 4 1/2 10,000 13558 9,300 12609 3 1/2 Slim Hole 4 1/4 API NC 35 4 3/4 5 3 1/2 Extra Hole or 4 1/4 4 Slim Hole or 4 1/2 4 3/4 3 1/2 Mod. Open 5 5 1/4 50 Foot-Pound Newton-Meters Bore of Drill Collar (in) 1 3/4 2 2 1/4 2 1/2 *8,900 *12067 9,200 12474 9,200 12474 *5,100 6915 *8,400 11389 10,000 13558 10,000 13558 10,000 13558 7,400 10033 7,400 10033 7,400 10033 *5,100 6915 *8,200 11118 8,200 11118 8,200 11118 8,200 11118 2,900 3932 2,900 3932 2,900 3932 3,700 5017 3,700 5017 *4,100 *5559 *5,300 7186 7,400 10033 *4,600 *6237 *4,600 *6237 *7,300 *9897 6,800 9220 8,100 10982 6,800 9220 8,100 10982 6,800 9220 *8,900 *12067 12,100 16405 12,100 16405 *5,100 6915 *8,400 *11389 *11,900 *16134 13,200 17897 13,200 17897 *8,900 *12067 *10,800 14643 10,800 14643 *5,100 6915 *8,400 11389 11,700 15863 11,700 15863 11,700 15863 51 2 13/16 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Size Connection Type 3 1/2 API IF or OD (in) 4 3/4 API NC 38 or 5 5 1/4 4 1/2 Slim Hole 5 1/2 4 3/4 5 3 1/2 H 904 5 1/4 5 1/2 4 Full Hole 5 API NC 40 or 5 1/4 4 Mod Open or 5 1/2 5 3/4 4 1/2 Dbl. Streamline 6 5 1/4 5 1/2 4 H 904 5 3/4 6 6 1/4 5 1/2 5 3/4 4 1/2 API Regular 6 6 1/4 52 Bore of Drill Collar (in) 1 1 1/4 1 1/2 Foot-Pound Newton-Meters Bore of Drill Collar (in) 1 3/4 2 2 1/4 2 1/2 *9,900 13423 *9,900 13423 *9,900 13423 *9,900 13423 *8,300 *11253 *13,800 *18710 *13,800 *18710 12,800 17354 10,900 14778 8,300 11253 16,000 21693 14,600 19795 12,800 17354 10,900 14778 8,300 11253 16,000 21693 14,600 19795 12,800 17354 10,900 14778 8,300 11253 *8,700 *11796 *8,700 *11796 *8,700 *11796 *8,700 *11796 *8,700 *11796 *12,700 *17219 *12,700 *17219 *12,700 *17219 12,700 17219 10,400 14101 *16,900 *22913 16,700 22642 15,000 20337 13,100 17761 10,400 14101 18,500 25083 16,700 22642 15,000 20337 13,100 17761 10,400 14101 *10,800 *14643 *10,800 *14643 *10,800 *14643 *10,800 *14643 *10,800 *14643 *15,100 *20473 *15,100 *20473 *15,100 *20473 14,800 20066 12,100 16405 *19,700 *26710 18,600 25218 16,900 22913 14,800 20066 12,100 16405 20,400 27659 18,600 25218 16,900 22913 14,800 20066 12,100 16405 20,400 27659 18,600 25218 16,900 22913 14,800 20066 12,100 16405 *12,500 *16948 *12,500 *16948 *12,500 *16948 *12,500 *16948 *17,300 *23456 *17,300 *23456 *17,300 *23456 *16,500 22371 *22,300 *30235 21,500 *29150 19,400 26303 16,500 22371 23,500 31862 21,500 29150 19,400 26303 16,500 22371 23,500 31862 21,500 29150 19,400 26303 16,500 22371 *15,400 *20880 *15,400 *20880 *15,400 *20880 *15,400 *20880 *20,300 *27523 *20,300 *27523 19,400 26303 16,200 21964 23,400 31726 21,600 29286 19,400 26303 *16,200 21964 23,400 31726 21,600 29286 19,400 26303 16,200 21964 53 2 13/16 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Connection Size API 4 1/2 Type Bore of Drill Collar (in) OD (in) 5 1/4 25,000 33895 6 1/2 25,000 33895 5 1/2 *12,900 *17490 5 3/4 *17,900 *24269 6 *23,300 *31591 6 1/4 27,000 36607 6 1/2 27,000 36607 5 3/4 API NC 46 6 4 API IF 6 1/4 Semi F 6 1/2 5 Dbl Streamline 6 3/4 4 1/2 Mod Open 6 3/4 5 3/4 6 4 1/2 H 904 6 1/4 6 1/2 6 3/4 6 1/4 6 1/2 5 *20,600 *27930 6 1/4 Extra Hole 4 2 25,000 33895 4 1/2 1/ 2 1 3/4 6 NC 44 API Full Hole 1 1/2 H 904 6 3/4 7 54 Foot-Pound Newton-Meters Bore of Drill Collar (in) 2 1/4 2 1/2 2 13/16 *20,600 *27930 *20,600 *27930 18,000 24405 23,300 31591 21,200 28743 18,000 24405 23,300 31591 21,200 28743 18,000 24405 23,300 31591 21,200 28743 18,000 24405 *12,900 *17490 *12,900 *17490 *12,900 *17490 *12,900 *17490 *17,900 *24269 *17,900 *24269 *17,900 *24269 17,700 23998 *23,300 *31591 22,800 30913 19,800 26845 17,700 23998 *25,000 33895 22,800 30913 19,800 26845 17,700 23998 25,000 33895 22,800 30913 19,800 26845 17,700 23998 *17,600 *23862 *17,600 *23862 *17,600 *23862 *17,600 *23862 *23,200 31455 *23,200 31455 22,200 30099 20,200 27388 28,000 37963 25,500 34573 22,200 30099 20,200 27388 28,000 37963 25,500 34573 22,200 30099 20,200 27388 28,000 37963 25,500 34573 22,200 30099 20,200 27388 *17,600 *23862 *17,600 *23862 *17,600 *23862 *17,600 *23862 *23,400 *31726 *23,400 *31726 23,000 31184 21,000 28472 28,500 38641 26,000 35251 23,000 31184 21,000 28472 28,500 38641 26,000 35251 23,000 31184 21,000 28472 28,500 38641 26,000 35251 23,000 31184 21,000 28472 *25,000 *33895 *25,000 *33895 *25,000 *33895 *25,000 *33895 *31,500 *42708 *31,500 *42708 29,500 39997 27,000 36607 35,000 47453 33,000 44742 29,500 39997 27,000 36607 35,000 47453 33,000 44742 29,500 39997 27,000 36607 55 3 3 1/4 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Size Connection Type Bore of Drill Collar (in) 2 2 1/4 2 1/2 OD (in) 4 1/2 API IF or 6 1/4 API NC 50 or 6 1/2 5 Extra Hole or 6 3/4 5 Mod Open or 7 5 1/2 Dbl. Streamline or Semi IF 7 1/4 *22,800 *30913 *29,500 39997 *36,000 *48809 38,000 51521 38,000 51521 *34,000 *46098 *22,800 *30913 *29,500 *39997 35,500 48132 35,500 48132 35,500 48132 *34,400 46640 *41,500 *56266 40,000 54233 7 1/4 42,500 57622 40,000 54233 7 1/2 42,500 57622 40,000 54233 6 3/4 *31,500 *42708 *31,500 *42708 7 *39,000 *52877 *39,000 *52877 7 1/4 42,000 56944 39,500 53555 7 1/2 42,000 56944 39,500 53555 6 3/4 7 5 1/2 5 1/2 H 904 API Regular 7 *32,500 *44064 *40,500 *54911 *49,000 66435 51,500 69825 *40,000 54233 *48,500 *65757 51,000 69147 51,000 69147 7 1/4 5 1/2 API Full Hole 7 1/2 7 3/4 7 1/4 7 1/2 API NC 56 7 3/4 8 56 Foot-Pound Newton-Meters Bore of Drill Collar (in) 2 13/16 *22,800 *30913 *29,500 *39997 32,200 43657 32,000 43386 32,000 43386 *34,000 *46098 36,500 49487 36,500 49487 36,500 49487 *31,500 *42708 36,000 48809 36,000 48809 36,000 48809 32,500 44064 *40,500 *54911 47,000 63723 47,000 63723 *40,000 *54233 48,000 65079 48,000 65079 48,000 65079 3 *22,800 *30913 *29,500 *39997 30,000 40675 30,000 40675 30,000 40675 34,000 46098 34,000 46098 34,000 46098 34,000 46098 *31,500 *42708 33,500 45420 33,500 45420 33,500 45420 32,500 44064 *40,000 *54233 45,000 61012 45,000 61012 *40,000 *54233 45,500 61690 45,000 61012 45,000 61012 3 1/4 *22,800 *30913 26,500 35929 26,500 35929 26,500 35929 26,500 35929 *32,500 *44064 *40,500 *54911 41,500 56266 41,500 56266 *40,000 *54233 42,000 56944 42,000 56944 42,000 56944 57 3 1/2 3 3/4 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Size Connection Type 6 5/8 6 5/8 API 5 1/2 Bore of Drill Collar (in) 2 2 1/4 2 1/2 OD (in) 7 1/2 *46,000 *62368 7 3/4 *55,000 *74570 API Regular H 904 NC 61 8 57,000 77282 8 1/4 57,000 77282 7 1/2 *46,000 *62368 7 3/4 *55,000 *74570 8 59,500 *80671 8 1/4 59,500 80671 8 *54,000 *73214 8 1/4 *64,000 *86772 8 1/2 72,000 97619 8 3/4 72,000 97619 9 72,000 97619 8 *56,000 *75926 8 1/4 *66,000 *89484 8 1/2 74,000 100331 8 3/4 74,000 100331 9 74,000 100331 9 1/4 74,000 100331 API IF 8 1/2 8 3/4 6 5/8 API Full Hole 9 9 1/4 9 1/2 58 Foot-Pound Newton-Meters Bore of Drill Collar (in) 2 13/16 3 3 1/4 *46,000 *62368 *46,000 *62368 *46,000 *62368 53,000 71858 50,000 67791 47,000 63723 53,000 71858 50,000 67791 47,000 63723 53,000 71858 50,000 67791 47,000 63723 *46,000 *62368 *46,000 *62368 *46,000 *62368 55,000 *74570 53,000 71858 49,500 67113 *56,000 *75926 53,000 71858 49,500 67113 56,000 75926 53,000 71858 49,500 67113 *54,000 *73214 *54,000 *73214 *54,000 *73214 *64,000 *86772 *64,000 *86772 61,000 82705 68,000 92196 65,000 88128 61,000 82705 68,000 92196 65,000 88128 61,000 82705 68,000 92196 65,000 88128 61,000 82705 *56,000 *75926 *56,000 *75926 *56,000 *75926 *56,000 *75926 *66,000 *89484 *66,000 *89484 63,000 85417 59,000 79993 70,000 94907 67,000 90840 63,000 85417 59,000 79993 70,000 94907 67,000 90840 63,000 85417 59,000 79993 70,000 94907 67,000 90840 63,000 85417 59,000 79993 70,000 94907 67,000 90840 63,000 85417 59,000 79993 *67,000 *90840 *67,000 *90840 *67,000 *90840 *67,000 *90840 66,500 90162 *78,000 *105754 *78,000 *105754 76,000 103042 72,000 97619 66,500 90162 83,000 112533 80,000 108465 76,000 103042 72,000 97619 66,500 90162 83,000 112533 80,000 108465 76,000 103042 72,000 97619 66,500 90162 83,000 112533 80,000 108465 76,000 103042 72,000 97619 66,500 90162 59 3 1/2 3 3/4 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Connection Size Type Bore of Drill Collar (in) OD (in) 2 9 9 1/4 9 1/2 API NC 70 9 3/4 10 10 1/4 10 10 1/4 API NC 77 10 1/2 10 3/4 11 8 7 H 904 8 1/4 8 1/2 8 1/2 8 3/4 7 5/8 API Regular 9 9 1/4 9 1/2 9 7 5/8 H 904 9 1/4 9 1/2 60 2 1/4 2 1/2 Foot-Pound Newton-Meters Bore of Drill Collar (in) 2 13/16 3 3 1/4 3 1/2 3 3/4 *75,000 *101686 *75,000 *101686 *75,000 *101686 *75,000 *101686 *75,000 *101686 *88,000 *119312 *88,000 *119312 *88,000 *119312 *88,000 *119312 *88,000 *119312 *101,000 *136938 *101,000 *136938 100,000 135582 95,000 128803 90,000 122024 107,000 145073 105,000 142361 100,000 135582 95,000 128803 90,000 122024 107,000 145073 105,000 142361 100,000 135582 95,000 128803 90,000 122024 107,000 145073 105,000 142361 100,000 135582 95,000 128803 90,000 122024 *107,000 *145073 *107,000 *145073 *107,000 *145073 *107,000 *145073 *122,000 *165410 *122,000 *165410 *122,000 *165410 *122,000 *165410 *138,000 *187103 *138,000 *187103 133,000 180324 128,000 173545 143,000 193882 138,000 187103 133,000 180324 128,000 173545 143,000 193882 138,000 187103 133,000 180324 128,000 173545 *53,000 *71858 *53,000 *71858 *53,000 *71858 *53,000 *71858 *63,000 *85417 *63,000 *85417 *63,000 *85417 60,500 *82027 71,500 96941 68,500 92874 65,000 88128 60,500 82027 *60,000 *81349 *60,000 *81349 *60,000 *81349 *60,000 *81349 *71,000 *96263 *71,000 *96263 *71,000 *96263 *71,000 *96263 *83,000 *112533 *83,000 *112533 79,000 107110 74,000 100331 88,000 119312 83,000 112532 79,000 107110 74,000 100331 88,000 119312 83,000 112532 79,000 107110 74,000 100331 *72,000 *97619 *72,000 *97619 *72,000 *97619 *72,000 *97619 *85,500 *115922 *85,500 *115922 *85,500 *115922 *85,500 *115922 *98,000 *132870 *98,000 *132870 *98,000 *132870 95,500 129481 61 Recommended Minimum Make-up Torque for Rotary Shouldered Drill Collar Connections Size Connection Type Bore of Drill Collar (in) 2 2 1/4 2 1/2 OD (in) 10 8 5/8 API Regular 10 1/4 10 1/2 8 5/8 H 904 10 1/4 10 1/2 7 H 904 8 3/4 (with low torque face) 9 9 1/4 7 5/8 API Regular 9 1/2 (with low torque face) 9 3/4 10 9 3/4 10 7 5/8 H 904 (with low torque face) 10 1/4 10 1/2 8 5/8 API Regular 10 3/4 (with low torque face) 11 10 3/4 8 5/8 H 904 11 (with low torque face) 11 1/4 *NOTE 1: Torque figures preceded by an asterisk indicate that the weaker member for the corresponding outside diameter (OD) and bore is the BOX. For all other torque values the weaker member is the PIN. NOTE 2: In each connection size and type group, torque values apply to all connection types in the group, when used with the same drill collar outside diameter and bore, i.e. 2 3/8, API IF, API NC 26, and 2 7/8 Slim Hole connections used with 3 1/2 x 1 1/4 drill collars all have the same minimum make-up torque of 4,600 ft.-lb., and the BOX is the weaker member. 62 Foot-Pound Newton-Meters Bore of Drill Collar (in) 2 13/16 *67,500 *91518 74,000 100331 3 *108,000 *146428 *123,000 *166766 139,000 188459 *112,500 *152530 *128,500 *174223 *67,500 *91518 71,000 96263 *72,000 *97619 *85,000 *115245 91,000 123379 91,000 123379 *91,000 *123379 *105,000 *142361 112,500 152530 112,500 152530 *112,000 *151852 *129,000 *174901 *92,500 *125413 *110,000 *149140 *128,000 *173545 3 1/4 *108,000 *146428 *123,000 *166766 134,000 181680 *112,500 *152530 *128,500 *174223 66,500 90162 66,500 90162 *72,000 *97619 *85,000 *115245 87,000 117956 87,000 117956 *91,000 *123379 *105,000 *142361 108,000 146428 108,000 146428 *112,000 *151852 *129,000 *174901 *92,500 *125413 *110,000 *149140 *128,000 *173545 3 1/2 *108,000 *146428 *123,000 *166766 129,000 174901 *112,500 *152530 *128,500 *174223 62,000 84061 62,000 84061 *72,000 *97619 82,000 111177 82,000 111177 82,000 111177 *91,000 *123379 103,500 140327 103,500 140327 103,500 140327 *112,000 *151852 *129,000 *174901 *92,500 *125413 *110,000 *149140 *128,000 *173545 3 3/4 *108,000 *146428 *123,000 *166766 123,000 166766 *112,500 *152530 *128,500 *174223 *72,000 *97619 77,000 104398 77,000 104398 77,000 104398 *91,000 *123379 98,000 132870 98,000 132870 98,000 132870 *112,000 *151852 *129,000 *174901 *92,500 *125413 *110,000 *149140 *128,000 *173545 1 Basis of calculations for recommended make-up torque assumed the use of a thread compound containing a 0.08 coefficient of friction, applied thoroughly to all threads and shoulders, and using the modified Jack Screw formula in Appendix A, paragraph A.8 and a unit stress of 62,500 psi in the box or pin, whichever is weaker. 2 Normal torque range is tabulated value plus 10%. Higher torque values may be used under extreme conditions. 3 Make-up torque for 27/8 PAC connection is based on 87,500 psi stress and other factors listed in footnote1. 4 Make-up torque for H-90 connection is based on 56,200 psi stress and other factors listed in footnote1. 63 Groove Machining For Elevators and Slips ELEVATOR SLIP DRILL COLLAR OD GROOVE DIA GROOVE DIA RADIUS A B +- 1/64 C +- 1/32 R 4 1/8 3 11/16 3 3/4 1/8 4 3/4 4 1/4 4 3/8 1/8 5 4 1/2 4 5/8 1/8 5 1/4 4 3/4 4 7/8 1/8 5 1/2 5 5 1/8 1/8 5 3/4 5 1/8 5 1/4 1/8 6 5 3/8 5 1/2 1/8 6 1/4 5 5/8 5 3/4 1/8 6 1/2 5 7/8 6 1/8 6 3/4 6 6 1/4 3/16 7 6 1/4 6 1/2 3/16 7 1/4 6 1/2 6 3/4 3/16 7 1/2 6 3/4 7 3/16 7 3/4 7 7 1/4 3/16 8 7 1/4 7 1/2 3/16 8 1/4 7 1/2 7 3/4 3/16 8 1/2 7 3/4 8 3/16 9 8 1/8 8 1/2 1/4 9 1/2 8 5/8 9 1/4 9 3/4 8 7/8 9 1/4 1/4 10 9 1/8 9 1/2 1/4 11 10 1/8 10 1/2 1/4 64 NOTE: ON REWORK, MINIMUM DISTANCE FROM FACE OF BOX TO ELEVATOR SHOULDER OR END OF HARDBANDING SHOULD BE A LENGTH EQUIVALENT TO DEPTH OF BOX OR BOREBACK PLUS TWO INCHES Hardbanding 65 Drill Collar Weight lb/ft, kg/m Drill Collar OD (in) 2 7/8 3 3 1/8 3 1/4 3 1/2 3 3/4 4 4 1/8 4 1/4 4 1/2 4 3/4 5 5 1/4 5 1/2 5 3/4 6 6 1/4 6 1/2 6 3/4 7 7 1/4 7 1/2 7 3/4 Drill Collar ID (in) 1 1 1/4 19 28 21 31 22 33 26 39 30 45 35 52 40 60 43 64 46 68 51 76 18 27 20 30 22 33 24 36 29 43 33 49 39 58 41 61 44 65 50 74 1 1/2 1 3/4 16 24 18 27 20 30 22 33 27 40 32 48 37 55 39 58 42 62 48 71 54 80 61 91 68 101 75 112 82 122 90 134 98 146 107 159 116 172 125 186 134 199 144 214 154 229 35 52 37 55 40 60 46 68 52 77 59 88 65 97 73 108 80 119 88 131 96 143 105 156 114 170 123 183 132 196 142 211 152 226 66 2 32 48 35 52 38 56 43 64 50 74 56 83 63 94 70 104 78 116 85 126 94 140 102 152 111 165 120 179 130 193 139 207 150 223 2 1/4 29 43 32 48 35 52 41 61 47 70 53 79 60 89 67 100 75 112 83 124 91 135 99 147 108 161 117 174 127 189 137 204 147 218 Pound per foot Kilogram per meter 2 1/2 44 65 50 74 57 85 64 95 72 107 79 118 88 131 96 143 105 156 114 170 124 184 133 198 144 214 2 13/16 60 89 67 100 75 111 83 123 91 135 100 149 110 163 119 177 129 192 139 207 3 3 1/4 3 1/2 3 3/4 4 64 95 72 107 80 119 89 132 98 146 107 159 116 172 126 187 136 202 60 89 68 101 76 113 85 126 93 138 103 153 112 166 122 181 132 196 72 107 80 119 89 132 98 146 108 161 117 174 128 190 93 138 103 153 113 168 123 183 84 125 93 138 102 152 112 166 67 Drill Collar Weight lb/ft, kg/m Drill Collar OD (in) Drill Collar ID (in) 1 1 1/4 8 8 1/4 8 1/2 9 9 1/2 9 3/4 10 11 12 1 1/2 1 3/4 2 165 245 176 262 187 278 210 312 234 348 248 369 261 388 317 471 379 563 163 242 174 257 185 275 208 309 232 345 245 364 259 385 315 468 377 560 160 238 171 254 182 270 206 306 230 342 243 361 257 382 313 465 374 557 2 1/4 157 233 168 250 179 266 203 302 227 337 240 357 254 377 310 461 371 551 Note 1: Refer to API Spec. 7 Latest Edition for API standard drill collar dimensions. 31ft (lb), 31 ft (kg) Drill Collar OD (in) 2 7/8 3 3 1/8 3 1/4 3 1/2 3 3/4 4 4 1/8 4 1/4 Drill Collar ID (in) 1 1 1/4 589 267 651 295 682 309 806 365 930 422 1,085 492 1,240 562 1,333 604 1,426 647 558 253 620 281 682 309 744 337 899 407 1,023 463 1,209 548 1,271 577 1,364 619 1 1/2 496 225 558 253 620 281 682 309 837 400 992 450 1,147 520 1,209 548 1,302 590 68 1 3/4 1,085 492 1,147 520 1,240 562 2 992 450 1,085 492 1,178 534 2 1/4 899 407 992 450 1,085 492 Pound per foot Kilogram per meter 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4 154 229 165 245 176 262 200 297 224 333 237 352 251 373 307 456 368 547 150 223 160 238 172 256 195 290 220 327 232 345 246 366 302 449 364 541 147 218 158 235 169 251 192 285 216 321 229 340 243 361 299 444 361 537 143 213 154 229 165 245 188 279 212 315 225 334 239 355 295 438 357 531 138 205 149 221 160 238 184 273 209 311 221 328 235 349 291 432 352 523 133 198 144 214 155 230 179 266 206 306 216 321 230 342 286 425 347 516 122 181 133 198 150 223 174 259 198 294 211 314 225 334 281 418 342 508 NOTE 2: For special configurations of drill collars, consult manufacturer for reduction in weight. Pound Kilogram 2 1/2 2 13/16 3 3 1/4 69 3 1/2 3 3/4 4 Drill Collar Weight 31ft(lb), 31ft(kg) Drill Collar OD (in) 4 1/2 4 3/4 5 5 1/4 5 1/2 5 3/4 6 6 1/4 6 1/2 6 3/4 7 7 1/4 7 1/2 7 3/4 8 8 1/4 8 1/2 9 9 1/2 9 3/4 10 11 12 Drill Collar ID (in) 1 1,581 717 1 1/4 1,550 703 1 1/2 1,488 675 1,674 759 1,891 857 2,108 956 2,325 1,055 2,542 1,152 2,790 1,266 3,038 1,378 3,317 1,505 3,596 1,631 3,875 1,758 4,154 1,884 4,464 2,025 4,774 2,165 5,115 2,320 5,456 2,475 5,797 2,629 6,510 2,953 7,254 3,290 7,688 3,487 8,091 3,670 9,827 4,457 11,749 5,329 1 3/4 2 2 1/4 1,426 1,333 1,271 646 604 576 1,612 1,550 1,457 731 703 660 1,829 1,736 1,643 829 787 745 2,015 1,953 1,860 913 885 843 2,263 2,170 2,077 1,026 984 942 2,480 2,418 2,325 1,125 1,097 1,055 2,728 2,635 2,573 1,237 1,195 1,167 2,976 2,914 2,821 1,350 1,322 1,280 3,255 3,162 3,069 1,476 1,434 1,392 3,534 3,441 3,348 1,603 1,561 1,519 3,813 3,720 3,627 1,730 1,687 1,645 4,092 4,030 3,937 1,856 1,828 1,786 4,402 4,309 4,247 1,997 1,955 1,926 4,712 4,650 4,557 2,137 2,109 2,067 5,053 4,960 4,867 2,292 2,250 2,208 5,394 5,301 5,208 2,447 2,404 2,362 5,735 5,642 5,549 2,601 2,559 2,517 6,448 6,386 6,293 2,925 2,897 2,854 7,192 7,130 7,037 3,262 3,234 3,192 7,595 7,533 7,440 3,445 3,417 3,375 8,029 7,967 7,874 3,642 3,614 3,572 9,765 9,703 9,610 4,429 4,401 4,359 11,687 11,594 11,501 5,301 5,259 5,217 Note 1: Refer to API Spec. 7 Latest Edition for API standard drill collars dimensions. Note 2: For special configurations of drill collars, consult mfg. for reduction in weight. 70 Pound Kilogram 2 1/2 2 13/16 3 3 1/4 3 1/2 1,364 618 1,550 703 1,767 801 1,984 899 2,232 1,012 2,449 1,111 2,728 1,237 2,976 1,350 3,255 1,476 3,534 1,603 3,844 1,744 4,123 1,870 4,464 2,024 4,774 2,165 5,115 2,320 5,456 2,475 6,200 2,812 6,944 3,150 7,347 3,333 7,781 3,529 9,517 4,317 11,408 5,175 1,860 843 2,077 942 2,325 1,055 2,573 1,167 2,821 1,280 3,100 1,406 3,410 1,547 3,689 1,673 3,999 1,814 4,309 1,955 4,650 2,109 4,960 2,250 5,332 2,419 6,045 2,742 6,820 3,093 7,192 3,262 7,626 3,459 9,362 4,247 11,284 5,118 1,984 899 2,232 1,012 2,480 1,125 2,759 1,251 3,038 1,378 3,317 1,505 3,596 1,631 3,906 1,772 4,216 1,912 4,557 2,067 4,898 2,222 5,239 2,376 5,952 2,700 6,696 3,037 7,099 3,220 7,533 3,417 9,269 4,204 11,191 5,076 1,860 843 2,108 956 2,356 1,069 2,635 1,195 2,883 1,308 3,193 1,448 3,472 1,575 3,782 1,715 4,092 1,856 4,433 2,011 4,774 2,165 5,115 2,320 5,828 2,644 6,572 2,981 6,975 3,164 7,409 3,361 9,145 4,148 11,067 5,020 2,232 1,012 2,480 1,125 2,759 1,252 3,038 1,378 3,348 1,519 3,627 1,645 3,968 1,800 4,278 1,940 4,619 2,095 4,960 2,250 5,704 2,587 6,479 2,939 6,851 3,108 7,285 3,304 9,021 4,092 10,912 4,950 71 3 3/4 4 2,883 2,604 1,308 1,181 3,193 2,883 1,448 1,308 3,503 3,162 1,589 1,434 3,813 3,472 1,730 1,575 4,123 3,782 1,870 1,715 4,464 4,123 2,025 1,870 4,805 4,650 2,180 2,109 5,549 5,394 2,517 2,447 6,386 6,138 2,897 2,784 6,696 6,541 3,037 2,967 7,130 6,975 3,234 3,164 8,866 8,711 4,022 3,951 10,757 10,602 4,879 4,809 72 Drill Collar Bending Strength Ratios 73 74 Drill Collar Bending Strength Ratios 75 76 Drill Collar Bending Strength Ratios 77 78 Drill Collar Bending Strength Ratios 79 80 Drill Collar Bending Strength Ratios 81 82 Drill Collar Bending Strength Ratios 83 84 Drill Collar Bending Strength Ratios 85 Interchangeable Connection Table Connection Name Numbered Connection (NC) Size 26 31 Internal Flush (IF) 2 3/8 2 7/8 Slim Hole (SH) 2 7/8 3 1/2 Full Hole (FH) Double Streamline (DSL) 3 1/2 Extra Hole (XH) 2 7/8 External Flush (EF) 86 38 40 3 1/2 4 46 50 4 4 1/2 4 1/2 4 4 1/2 5 1/2 4 1/2 3 1/2 4 1/2 87 5 Ideal Drill Collar Range Hole Size (in) Casing Size To Be Run (in) Ideal Drill Min. (in) 6 1/8 4 1/2 3.875 6 1/4 4 1/2 3.750 6 /4 1 4 /2 3.250 4 1/2 2.125 1 5 /2 4.225 5 1/2 3.725 6 5/8 6.405 3 7 7/8 8 3/8 6 /8 6.280 5 8 1/2 8 3/4 9 1/2 9 7/8 10 5/8 7 *6.812 6 5/8 6.030 7 6.562 7 6.812 7 5/8 7.500 7 5.437 7 5/8 7.125 7 5/8 6.375 8 /8 *8.625 8 5/8 8.250 5 11 9 /8 9.000 5 12 1/4 10 3/4 *11.250 13 3/4 10 3/4 9.750 14 /4 11 /4 10.750 17 1/2 13 3/8 11.250 20 16 14.000 24 18 5/8 15.500 26 20 16.000 3 3 * The minimum size drill collar, calculated from the Lubinski and Hock equation, with the specific sizes of hole and casing combination, is too large for conventional fishing tools. When the minimum drill collar diameter is too large to washover and/or catch with an overshot, other steps should be taken. Some of the possibilities are as follows: • Use turned down casing couplings. • Use integral joints on casing. • Under-ream the hole. • Run smaller size casing. * Use a packed hole assembly instead of a pendulum. ** Not API standard size drill collar. 88 Collar Range API Drill Collar Max. (in) Sizes Which Fall in the Ideal Range (in) 4.750 4 1/8, 4 3/4 4.875 4 1/8, 4 3/4 5.125 3 1/2, 4 1/8, 4 3/4, 5 6.250 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4 6.250 4 3/4, 5, 6, 6 1/4 6.750 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4 6.750 6 1/2, 6 3/4 6.750 6 1/2, 6 3/4 6.750 6 3/4 7.125 6 1/4, 6 1/2, 6 3/4, 7 7.125 6 3/4, 7 7.625 6, 6 1/4, 6 1/2, 7, 7 1/4 7.875 7 3/4 8.000 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8 8.000 7 1/4, 7 3/4, 8 8.500 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4 8.500 8 1/4 8.875 8 1/4 10.125 9, 9 1/2, 9 3/4, 10 10.125 10 11.250 9 3/4, 10, 11 12.000 11, **12 13.375 **12 14.750 **14 16.750 **16 19.500 **16 89 Rig Tongs TONG TYPE JAW CAPACITY SIZES (in) (ft-lbs.) APPLICABLE API DRILL COLLAR SIZES (in) B.J. HUGHES COMPANY 1 1 3 SXD 8 - 16 200,000 8, 8 /4, 9, 9 /2, 9 /4, 10, 11 SDD 4 - 12 100,000 4 /8, 4 /4, 5, 6, 6 /4, 6 /2, 1 3 3 1 1 1 3 1 6 /4,7, 7 /4, 7 /4, 8, 8 /4, 9, 1 3 1 1 9 /2, 9 /4, 10 DB 3 1/2 - 11 1/4 3 1 1 3 /2, 4 /8, 4 /4, 5, 6, 6 /4, 6 /2, 65,000 3 1 3 1 6 /4, 7, 7 /4, 7 /4, 8, 8 /4 B 3 1/2 - 9 1 1 3 1 1 3 /2, 4 /8, 4 /4, 5, 6, 6 /4, 6 /2, 55,000 3 1 3 6 /4, 7, 7 /4, 7 /4, 8 C 3 3 2 /8 - 10 /4 1 1 1 1 1 3 1 1 1 3 3 /8, 3 /2, 4 /8, 4 /4, 5, 6, 35,000 6 /4, 6 /2, 6 /4 3 F 2 3/8 - 10 3/4 ST-160 7 1/2 - 12 160,000 7 /4, 8, 8 /4, 9, 9 /2, 9 /4, ST-60 4 - 9 5/8 60,000 4 /8,, 4 /4, 5, 6, 6 /4, 6 /2, 3 /8, 3 /2, 4 /8, 4 /4, 5, 6 25,000 JOY-WEB WILSON COMPANY 3 1 1 3 10 11 1 3 3 1 1 1 3 6 /4,7, 7 /4, 7 /4, 8 H 3 1/2 - 10 3/4 1 1 3 1 3 /2, 4 /8, 4 /4, 5, 6, 6 /4, 80,000 1 1 3 1 6 /2, 7, 7 /4, 7 /4, 8, 8 /4, 9 AAX 2 7/8 - 7 1/4 1 1 1 1 1 3 1 1 1 1 1 3 3 3 /8, 3 /2, 4 /8,, 4 /4,, 5, 6, 55,000 1 6 /4, 6 /2, 6 /4, 7, 7 /4, 8 B 2 3/8 - 8 5/8 3 3 /8, 3 /2, 4 /8, 4 /4, 5, 6, 35,000 6 /4, 6 /2, 6 /4 WOOLLEY COMPANY SDD 4 - 12 100,000 1 3 1 1 4 /8, 4 /4, 5, 6, 6 /4, 6 /2, 3 1 3 1 6 /4, 7, 7 /4, 7 /4, 8, 8 /4, 1 3 9, 9 /2, 9 /4, 10 SUPER A 3 1/2 - 11 1/4 1 1 3 1 3 /2,, 4 /4, 4 /4 ,5, 6, 6 /4, 65,000 1 3 1 1 1 3 1 6 /2, 6 /4, 7, 7 /4, 7 /4, 8, 8 /4 SUPER B 1 /2 - 9 3 1 3 /2, 4 /8, 4 /4, 5, 6, 6 /4, 6 /2, 55,000 1 7, 7 /4, 8 SUPER C 2 3/8 - 7 1 1 1 1 1 1 3 3 3 /8, 3 /2, 4 /8, 4 /4, 5, 6, 35,000 6 /4, 6 /2, 6 /4 90 Kellys KELLYS 91 Kelly Weights Pounds Per Foot (Drive Section) Square Kelly Across Flat 11/16 11/4 11/2 21/2 3 Bore of Square Kelly 13/4 2 21/4 21/2 23/4 27/8 3 31/4 31/2 18.3 17.1 25.8 24.0 31/2 35.6 21.8 33.5 31.0 28.2 41/4 47.9 51/4 44.7 41.3 39.3 73.5 71.6 69.7 65.5 61.0 6 89.6 Hexagon Kelly Across Flat 11/4 11/2 13/4 3 Bore of Hexagon Kelly 2 21/4 21/2 23/4 27/8 3 31/4 31/2 4 22.3 20.5 31/2 30.1 27.9 25.4 22.6 33/4 35.3 33.2 30.7 27.9 41/4 39.6 36.4 427/32 56.4 53.3 51/4 32.9 31.0 49.8 47.9 45.9 41.7 60.9 59.0 57.1 52.9 48.4 6 73.5 63.2 92 93 Picking Up a New Kelly Under ideal conditions, a new Drive Bushing assembly should be used when picking up a new kelly. If this is not possible, the following checklist should be performed: 1. Inspect surfaces on Drive Bushing rollers for wear. Example: For a 51/4 inch Hex, if wear exceeds 1/8 inch, reverse the rollers. 2. Check clearance between roller face and side of kelly. Example: For a 51/4 inch Hex, if clearance is more than 1/8 inch, inspect roller assembly and Kelly Bushing for excessive wear. 3. Inspect bottom taper of Drive Pins for wear and damage. Replace as necessary. 4. Inspect for clearance between upper and lower halves, replace if clearance is zero. Remember, a worn out Drive Bushing can severely damage a new kelly. 94 Subs General Notes on Subs NOTES: 1. Other lengths may be specified customer, example 48 inches. by the 2. Fishing neck (tong space) length, unless specified otherwise, is one half the overall length of the sub. For example, 18 inch fishing neck (tong space) on a 36 inch sub; 24 inch on a 48 inch sub. 3. Bevel Diameters- Make sure the bevel diameters on the subs match the bevel diameters on the connections. SUBS 95 Types Of Subs 96 General Notes On Subs NOTES: 1. Other lengths may be specified by the customer, example 48 inches. 2. Fishing neck (tong space) length, unless specified otherwise, is one half the overall length of the sub. For example, 18 inch fishing neck (tong space) on a 36 inch sub; 24 inch on a 48 inch sub. 3. Bevel Diameters: A. If the connection is to screw onto a piece of Drill Pipe (pipe, D/P) use the bevel diameters listed on drawing HB1003 in the “Bevel Dia.” section of the Machining Handbook. B. If the connection is a Bit Box (with or without a float bore) use the bevel diameters listed in column B in the top chart of drawing HB1017 “Float Bore” in this section of the Machining Handbook. C. If the connection is to screw onto a Drill Collar (Collar, D/C) use the bevel diameters listed at the bottom of the drawing of the specified connection. 97 Kelly Saver Subs 98 Bit Sub Lift Sub 99 Bit Box Float Bores 100 Well Control Height of Kick (ft) = Pit Gain ÷ Annular Capacity in Bbls/ft Density of Kick Fluids (ppg) = MW – [(SICPSIDPP) ÷ Height of Kick ÷ 0.052] Approximate Typical Fluid Densities: Gas-2ppg, Oil-7ppg, Water-9ppg Lag Time Rule of Thumb: Pressure changes from choke movement will take about two seconds per 1000’ of depth to travel down the annulus and up the drill pipe to the DP gauge. Sacks of Barite needed to Weight-Up Mud = Bbls Mud x 14.7 x (KWM-OWM) ÷ (35.4-KWM) Volume Increase in Bbls from adding Barite = Sacks Added ÷ 14.9 Volume Increase in Bbls from adding Barite = (Gel) = Sacks Added ÷ 8.75 Triplex Pump Output (bbls/stk @ 100%) = 0.000243 x Stroke Length x (Liner Dia)2 Duplex Pump Outlet (bbl/stk @ 100%) = 0.000162 x Stroke x [(2 x Liner Dia2) - Rod Dia2] Annular Capacity (bbls/ft) = (ID2hole OD2pipe) ÷ 1029 WELL CONTROL 101 Well Control Capacity of DUPLEX Mud Pumps at 100% Efficiency Liner Dia Stroke Length (in) (in) 12 14 16 18 4 5 5 6 6 7 7 1/ 2 1/ 2 1/ 2 1/ 2 0.074 0.089 0.110 – – – – 0.082 – 0.104 0.113 0.128 0.141 0.154 0.170 0.183 0.203 0.213 0.238 0.241 0.275 – 0.128 0.158 0.192 0.228 0.267 0.310 Capacity of TRIPLEX Mud Pumps at 100% Efficiency Liner Dia Stroke Length (in) (in) 9 10 11 12 5 5 1/2 6 6 1/2 7 7 1/2 (in Bbls/stroke) (in Bbls/stroke) MW SICP SIDPP ppg KWM OWM DP Bbls Stk 0.055 0.061 0.067 0.073 0.066 0.074 0.081 0.088 0.079 0.087 0.096 0.105 0.092 0.103 0.113 0.123 0.107 0.119 0.131 0.143 0.123 0.137 0.150 0.164 Mud Weight Shut in casing pressure Shut in drill pipe pressure Pounds per gallon Kill Weight Mud Original Weight Mud Drill Pipe Barrels Stroke 102 API Standard Drill Pipe Capacity and Displacement Size OD (in) Size ID (in) Nominal Weight (lb/ft) Capacity (bbl/ft) Displacement (bbl/ft) 3/ 8 7/ 8 1/ 2 1/ 2 1.81 2.15 2.76 2.60 3.34 3.82 3.64 4.28 4.78 4.67 4.86 5.96 6.6 10.4 13.3 15.5 14.0 16.6 20.0 19.5 21.9 24.7 22.2 25.2 0.0032 0.0045 0.0074 0.0066 0.0108 0.0142 0.0129 0.0178 0.0222 0.0211 0.0229 0.0346 0.0028 0.0041 0.0051 0.0058 0.0057 0.0064 0.0077 0.0075 0.0087 0.0096 0.0087 0.0098 2 2 3 3 4 4 4 5 5 5 6 6 1/ 2 1/ 2 1/ 2 1/ 2 5/ 8 5/ 8 Heavy Weight Drill Pipe Size OD (in) 3 4 4 5 5 6 1/ 2 1/ 2 1/ 2 5/ 8 Size ID (in) 2.0625 2.5625 2.75 3.0 3.25 4.5 Weight (lb/ft) Capacity (bbl/ft) Displacement (bbl/ft) 25.3 29.7 41.0 49.3 61.5 72.0 0.00421 0.00645 0.00743 0.00883 0.01030 0.01970 0.00921 0.01082 0.01493 0.01796 0.02240 0.02620 Additional capacities, displacements and weight can be determined from the following formulas: 2 CAPACITY = ID 1029.4 = bbls/ft 2 DISPLACEMENT = OD - ID 1029.4 2 = bbls/ft WEIGHT = DISPLACEMENT bbls/ft x 2747 lbs/bbl = lbs/ft 103 104 1 1/2 0.0022 36.7 0.0133 42.4 0.0153 48.1 0.175 54.3 0.0197 60.8 0.0221 67.6 0.0246 74.8 0.0272 82.3 0.0299 90.1 0.0328 98.0 0.0356 107.0 0.0389 ID Cap OD (in) #/ft. 4 Disp. #/ft. 4 1/4 Disp. 4 1/2 #/ft. Disp. 4 3/4 #/ft. Disp. 5 #/ft. Disp. 5 1/4 #/ft. Disp. 5 1/2 #/ft. Disp. 5 3/4 #/ft Disp. 6 #/ft. Disp. 6 1/4 #/ft. Disp. 6 1/2 #/ft. Disp. 34.5 0.0125 40.0 0.0145 45.9 0.0167 52.1 0.0189 58.6 0.0213 65.4 0.0238 72.6 0.0264 80.1 0.0291 87.9 0.0320 95.8 0.0349 104.8 0.0381 1 3/4 0.0030 32.0 0.0116 37.5 0.0136 43.4 0.0158 49.6 0.0181 56.1 0.0204 62.9 0.0229 70.1 0.0255 77.6 0.0282 85.4 0.0311 93.3 0.0339 102.3 0.0372 2 0.0039 29.2 0.106 34.7 0.0126 40.6 0.0148 46.8 0.0170 53.3 0.0194 60.1 0.0219 67.3 0.0245 74.8 0.0272 82.6 0.0301 90.5 0.0329 99.5 0.0362 2 1/4 0.0049 43.6 0.0159 50.1 0.0182 56.9 0.0207 64.1 0.0233 71.6 0.0261 79.4 0.0289 87.3 0.0318 96.3 0.0350 2 1/2 0.0061 53.4 0.0194 60.6 0.0221 68.1 0.0248 75.9 0.0276 83.8 0.0305 92.8 0.0338 2 3/4 0.0073 56.8 0.0207 64.3 0.0234 72.1 0.0262 80.0 0.0291 89.0 0.0324 3 0.0087 67.9 0.0247 75.8 0.0276 84.8 0.0308 3 1/4 0.0103 63.4 0.0231 71.3 0.0259 80.3 0.0292 3 1/2 0.0119 Drill Collar Capacity and Displacement (bbls/ft) - 3 3/4 0.0137 - - 4 4 1/4 0.0155 0.0175 105 10 9 8 3/4 8 1/2 8 1/4 8 7 3/4 7 1/2 7 1/4 7 6 3/4 #/ft. Disp. #/ft. Disp. #/ft. Disp. #/ft. Disp. #/ft. Disp. #/ft. Disp. #/ft Disp. #/ft. Disp. #/ft. Disp. #/ft. Disp. #/ft. Disp. ID Cap 116.0 0.0422 125.0 0.0455 134.0 0.0487 144.0 0.0524 154.0 0.0560 165.0 0.0600 176.0 0.0640 187.0 0.0680 199.0 0.0724 210.2 0.0765 260.9 0.0950 1 1/2 0.0022 113.8 0.0414 122.8 0.0447 131.8 0.0479 141.8 0.0516 151.8 0.0552 162.8 0.0592 173.8 0.0632 184.8 0.0672 196.8 0.0716 208.0 0.0757 258.8 0.0942 1 3/4 0.0030 111.3 0.0405 120.3 0.0438 129.3 0.0470 139.3 0.0507 149.3 0.0543 160.3 0.0583 171.3 0.0623 182.3 0.0663 194.3 0.0707 205.6 0.0748 256.3 0.0933 2 0.0039 108.5 0.0395 117.5 0.0427 126.5 0.0460 136.5 0.0497 146.5 0.0533 157.5 0.0573 168.5 0.0613 179.5 0.0653 191.5 0.0697 202.7 0.0738 253.4 0.0923 2 1/4 0.0049 105.3 0.0383 114.3 0.0416 123.3 0.0449 133.3 0.0485 143.3 0.0521 154.3 0.0561 165.3 0.0601 176.3 0.0641 188.3 0.0685 199.6 0.0726 250.3 0.0911 2 1/2 0.0061 101.8 0.0370 110.8 0.0403 119.8 0.0436 129.8 0.0472 139.8 0.0509 150.8 0.0549 161.8 0.0589 172.8 0.0629 184.8 0.0672 196.0 0.0714 246.8 0.0898 2 3/4 0.0073 98.0 0.0356 107.0 0.0389 116.0 0.0422 126.0 0.0458 136.0 0.0495 147.0 0.0535 158.0 0.0575 169.0 0.0615 181.0 0.0658 192.2 0.0700 242.9 0.0884 3 0.0087 93.8 0.0341 102.8 0.0374 111.8 0.0407 121.8 0.0443 131.8 0.0479 142.8 0.0520 153.8 0.0560 164.8 0.0600 176.8 0.0643 188.0 0.0685 238.8 0.0869 3 1/4 0.0103 89.3 0.0325 98.3 0.0358 107.3 0.0390 117.3 0.0427 127.3 0.0463 138.3 0.0503 149.3 0.0543 160.3 0.0583 172.3 0.0697 183.5 0.0668 234.3 0.0853 3 1/2 0.0119 93.4 0.0340 102.4 0.0372 112.4 0.0409 122.4 0.0445 133.4 0.0485 144.4 0.0525 155.4 0.0565 167.4 0.0609 178.7 0.0651 229.4 0.0835 3 3/4 0.0137 Drill Collar Capacity and Displacement (bbls/ft) (Cont.) 88.3 0.0321 97.3 0.0354 107.3 0.0390 117.3 0.0427 123.3 0.0467 139.3 0.0507 150.3 0.0547 162.3 0.0590 173.5 0.0632 224.2 0.0816 122.8 0.0447 133.8 0.0487 144.8 0.0527 156.8 0.0570 168.0 0.0612 218.7 0.0796 - 4 4 1/4 0.0155 0.0175 Buoyancy Factors Mud Density (lb/gal) (lb/cu ft) (g/cc) 8.4 8.6 8.8 9.0 9.2 9.4 9.6 9.8 10.0 10.2 10.4 10.6 10.8 11.0 11.2 11.4 11.6 11.8 12.0 12.2 12.4 12.6 12.8 13.0 13.2 13.4 13.6 13.8 62.84 64.33 65.83 67.32 68.82 70.32 71.81 73.31 74.80 76.30 77.80 79.29 80.79 82.29 83.78 85.28 86.77 88.27 89.77 91.26 92.76 94.25 95.75 97.25 98.74 100.24 101.74 103.23 1.01 1.03 1.05 1.08 1.10 1.12 1.15 1.17 1.20 1.22 1.24 1.27 1.29 1.32 1.34 1.36 1.39 1.41 1.44 1.46 1.48 1.51 1.53 1.56 1.58 1.60 1.63 1.65 106 Buoyancy Factor (Kb) 0.872 0.869 0.866 0.862 0.859 0.856 0.853 0.850 0.847 0.844 0.841 0.838 0.835 0.832 0.829 0.826 0.823 0.820 0.817 0.814 0.811 0.807 0.804 0.801 0.798 0.795 0.792 0.789 Mud Density (lb/gal) (lb/cu ft) 14.0 14.2 14.4 14.6 14.8 15.0 15.2 15.4 15.6 15.8 16.0 16.2 16.4 16.6 16.8 17.0 17.2 17.4 17.6 17.8 18.0 18.5 19.0 19.5 20.0 104.73 106.22 107.72 109.22 110.71 112.21 113.70 115.20 116.70 118.19 119.69 121.18 122.68 124.18 125.67 127.17 128.66 130.16 131.66 133.15 134.65 138.39 142.13 145.87 149.61 Buoyancy Factor (Kb) (g/cc) 1.68 1.70 1.72 1.75 1.77 1.80 1.82 1.84 1.87 1.89 1.91 1.94 1.96 1.99 2.01 2.03 2.06 2.08 2.11 2.13 2.15 2.21 2.27 2.33 2.39 107 0.786 0.783 0.780 0.777 0.774 0.771 0.768 0.765 0.762 0.759 0.756 0.752 0.749 0.746 0.743 0.740 0.737 0.734 0.731 0.728 0.725 0.717 0.710 0.702 0.694 Formulas Used In Well Control and Drilling Operations A. Calculating Pressure, psi and Pressure Gradients, psi/ft. 1. Determine pressure gradient, psi/ft. (Mud Weight, ppg.) x (0.052) = psi/ft. 2. Determine hydrostatic pressure, psi (H.P.) (Mud Wt., ppg.) x (0.052) x (T.V.D., ft.) = psi 3. Maximum allowable shut in casing pressure ( Maximum Allowable Mud Wt., ppg ) -( Mud Wt. in use ppg ) x(0.052)x(TVD, ft.)= psi Test to determine H2S 50 ml HCl (mild hydrochloric solution) 50 ml H2O 1 gram NaASO2 (sodium arsenite) 3 drop liquid dish water soap yellow positive sign won’t determine degree 108 B. Converting Pressures, psi into mud weight, ppg. (NOTE: Anytime a pressure is to be converted to mud weight, the following formula is used.) All of the following use the same formula: Pressure, psi = Mud Weight, ppg 0.052 x TVD, ft. Using the calculator, this formula is worked as follows: (Pressure, psi) ÷ (0.052) ÷ (TVD, ft) = Mud Weight, ppg. 1. Kill Weight Mud, ppg. (SIDPP, psi)- (0.052) - (TVD, ft) + (O.M.W.) = Kill Wt., ppg. 2. Equivalent Mud Weight = ppg. (E.M.W.) (pressure, psi) ÷ (0.052) ÷ (TVD, ft) = E.M.W., ppg 3. Equivalent Circulating Density, ppg (E.C.D.) ( Annular Pressure Loss, psi ) ÷ (0.052) ÷ (TVD, ft.) + (O.M.W.) = E.C.D., ppg 4. Maximum Allowable Mud Weight, ppg. ( Leak-Off Pressure psi ) ÷ (0.052) x (TVD, ft.)+ Test Mud = ppg. Weight ( ) 5. Converting Pressure Gradient, psi/ft to Mud Wt., ppg (Pressure Gradient, PSI/ft.) ÷ (0.052) = Mud Wt., ppg. O.M.W. (original mud weight) SIDPP (shut in drill pipe pressure) TVD (true vertical depth) 109 www.grantprideco.com REGIONAL OFFICES NORTH AMERICA REGION 1450 Lake Robbins Dr. Suite 400 The Woodlands, Texas 77380 281.297.8500 800.231.0283 Fax: 281.297.8535 CHINA Grant Prideco Suite C411B, Beijing Lufthansa Center No. 50 Liangmaqiao Rd, Chaoyang District Beijing, China 100016 011.86.10.8454.0093/0095 Fax: 011.86.10.8454.2229 CIS 229 Luke Lafayette, Louisiana 70506 337.232.3098 Fax: 337.261.1066 Grant Prideco 113114 Moscow, Russia Shluzovaya Nab. 6, Bldg. 1-2 011.70.95.960.2404 Fax: 011.70.95.960.2405 ABERDEEN S.E. 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