Grant Prideco Rotary Shoulder Handbook
eXtreme® Rotary Shoulder Handbook D RILLING P RODUCTS & S ERVICES www.grantprideco.com CONTENTS SECTION I Drill Pipe
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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)
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DISCLAIMER: 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. © 2004 Grant Prideco