Grant-Prideco-Rotary-Shoulder-Handbook

eXtreme ®
Rotary
Shoulder
Handbook
www.grantprideco.com
DRILLING PRODUCTS & SERVICES

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.

Drill Pipe
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.
DRILL PIPE
1

New Tool Joints
Torque Chart Drill Pipe Tool Joint
Drill Pipe Type Box Pin Make-up
Size Conn OD ID Torque
(in) (in) (in) (ft-lb)
N.C. 26 (I.F.) 3 3 / 8 1 3 / 4 3,900
O.H. 3 1 / 4 1 3 / 4 3,700
O.H. 3 1 / 8 2 2,600
2 3 / 8 S.L. H-90 3 1 / 4 2 2,700
W.O. 3 3 / 8 2 2,400
P.A.C. 2 7 / 8 1 3 / 8 2,600
2 7 / 8” S.H. (N.C. 26) 3 3 / 8 1 3 / 4 3,900
O.H. 3 3 / 4 2 7 / 16 3,100
O.H. 3 7 / 8 2 5 / 32 4,800
S.L. H-90 3 7 / 8 2 7 / 16 3,800
S.L. H-90 3 7 / 8 2 5 / 32 6,800
2 7 / 8 P.A.C. 3 1 / 8 1 1 / 2 3,200
W.O. 4 1 / 8 2 7 / 16 3,900
X.H. 4 1 / 4 1 7 / 8 7,000
N.C. 31 (I.F.) 4 1 / 8 2 1 / 8 6,400
N.C. 31 (I.F.) 4 1 / 8 2 7,100
N.C. 31 (I.F.) 4 3 / 8 1 5 / 8 4,400
3 1 / 2 S.H. (N.C. 31) 4 1 / 8 2 1 / 8 6,400
S.L. H-90 4 5 / 8 3 7,600
S.L. H-90 4 5 / 8 2 11 / 16 11,110
O.H. 4 3 / 4 3 6,500
O.H. 4 3 / 4 2 11 / 16 9,300
3 1 / 2 N.C. 38 (W.O.) 4 3 / 4 3 6,800
N.C. 38 (I.F.) 4 3 / 4 2 11 / 16 9,700
N.C. 38 (I.F.) 5 2 9 / 16 10,700
N.C. 38 (I.F.) 5 2 7 / 16 11,700
N.C. 38 (I.F.) 5 2 1 / 8 14,000
N.C. 40 (4” F.H.) 5 1 / 4 2 9 / 16 14,600
N.C. 40 (4” F.H.) 5 3 / 8 2 7 / 16 15,600
N.C. 40 (4” F.H.) 5 1 / 2 2 1 / 4 17,100
S.H. (3 1 / 2” X.H.) 4 5 / 8 2 9 / 16 8,100
O.H. 5 1 / 4 3 15 / 32 11,900
O.H. 5 1 / 2 3 1 / 4 14,700
N.C. 40 (4” F.H.) 5 1 / 4 2 13 / 16 12,400
N.C. 40 (4” F.H.) 5 1 / 4 2 11 / 16 13,500
N.C. 40 (4” F.H.) 5 1 / 2 2 7 / 16 15,600
N.C. 40 (4” F.H.) 5 1 / 2 2 7 / 16 15,600
4 N.C. 46 (W.O.) 5 3 / 4 3 7 / 16 15,200
N.C. 46 (I.F.) 6 3 1 / 4 17,600
N.C. 46 (I.F.) 6 3 20,500
N.C. 46 (I.F.) 6 3 20,500
N.C. 46 (I.F.) 6 3 1 / 4 17,600
N.C. 46 (I.F.) 6 3 20,500
N.C. 46 (I.F.) 6 2 5 / 8 24,400
N.C. 46 (I.F.) 6 2 7 / 8 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 Class 2
Box Make-Up Box Make-up
OD Torque OD Torque
(in) (ft-lb) (in) (ft-lb)
3 1 / 4 3,000 3 3 / 16 2,500
3 1 / 16 2,300 3 1 / 32 2,100
3 1,800 2 31 / 32 1,600
2 31 / 32 2,000 3 31 / 32 2,000
3 1 / 16 2,000 3 1,500
2 25 / 32 2,500 2 23 / 32 2,100
3 3 / 8 4,100 3 5 / 16 3,600
3 1 / 2 3,300 3 7 / 16 2,700
3 19 / 32 4,300 3 17 / 32 3,600
3 17 / 32 3,800 3 17 / 32 3,800
3 19 / 32 4,600 3 17 / 32 3,800
3 1 / 8 3,500 3 1 / 16 3,500
3 5 / 8 3,200 3 9 / 16 2,500
3 23 / 32 4,400 3 21 / 32 3,700
3 11 / 16 3,200 3 21 / 32 2,800
3 29 / 32 5,700 3 13 / 16 4,600
4 1 / 16 7,700 3 31 / 32 6,500
4 6,900 3 29 / 32 5,700
4 3 / 16 5,500 4 1 / 8 4,500
4 3 / 8 8,800 4 9 / 32 7,100
4 9 / 32 5,500 4 7 / 32 4,600
4 3 / 8 7,000 4 5 / 16 6,000
4 3 / 8 5,300 4 11 / 32 4,800
4 3 / 8 5,300 4 11 / 32 4,800
4 19 / 32 8,800 4 1 / 2 7,300
4 21 / 32 9,900 4 9 / 16 8,300
4 23 / 32 10,900 4 5 / 8 9,300
4 15 / 32 11,400 4 13 / 32 9,000
5 12,600 4 7 / 8 10,200
5 3 / 32 14,400 4 15 / 16 11,400
4 7 / 16 8,800 4 11 / 32 7,400
4 31 / 32 7,500 4 29 / 32 6,200
5 1 / 32 8,800 4 31 / 32 7,500
4 13 / 16 9,000 4 23 / 32 7,300
4 15 / 16 11,400 4 13 / 16 9,000
5 12,600 4 7 / 8 10,200
5 12,600 4 7 / 8 10,200
5 7 / 32 7,900 5 5 / 32 6,500
5 5 / 32 10,000 5 7 / 32 7,900
5 7 / 16 12,800 5 5 / 16 10,000
5 15 / 32 13,600 5 3 / 8 11,400
5 9 / 32 9,200 5 3 / 16 7,200
5 9 / 16 15,800 5 7 / 16 12,800
5 5 / 8 17,300 5 1 / 2 14,300
5 5 / 8 17,300 5 1 / 2 14,300
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 Type Box Pin Make-up
Size Conn OD ID Torque
(in) (in) (in) (ft-lb)
O.H. 5 7 / 8 3 3 / 4 14,600
F.H. 6 3 17,600
F.H. 6 2 3 / 4 20,100
F.H. 6 2 1 / 2 22,300
N.C. 46 (X.H.) 6 1 / 4 3 1 / 4 17,600
N.C. 46 (X.H.) 6 1 / 4 3 20,500
4 1 / 2 N.C. 46 (X.H.) 6 1 / 4 2 3 / 4 23,200
N.C. 46 (X.H.) 6 1 / 4 2 1 / 2 25,600
N.C. 50 (I.F.) 6 3 / 8 3 3 / 4 19,800
N.C. 50 (I.F.) 6 3 / 8 3 3 / 4 19,800
N.C. 50 (I.F.) 6 3 / 8 3 5 / 8 21,600
N.C. 50 (I.F.) 6 3 / 8 3 1 / 2 23,400
N.C. 50 (I.F.) 6 3 / 8 2 7 / 8 30,300
N.C. 50 (X.H.) 6 3 / 8 3 3 / 4 19,800
N.C. 50 (X.H.) 6 3 / 8 3 1 / 2 23,400
N.C. 50 (X.H.) 6 1 / 2 3 1 / 4 26,800
N.C. 50 (X.H.) 6 1 / 2 3 30,000
5 N.C. 50 (X.H.) 6 5 / 8 2 3 / 4 32,900
5 1 / 2” F.H. 7 3 1 / 2 37,400
5 1 / 2” F.H. 7 1 / 4 3 1 / 2 37,400
5 1 / 2” F.H. 7 1 / 4 3 1 / 4 41,200
F.H. 7 4 29,200
F.H. 7 4 29,200
F.H. 7 3 3 / 4 33,400
5 1 / 2 F.H. 7 1 / 4 3 1 / 2 37,400
F.H. 7 1 / 4 3 1 / 2 37,400
F.H. 7 1 / 4 3 1 / 2 37,400
F.H. 7 1 / 2 3 44,600
F.H. 7 1 / 2 3 44,600
F.H. 8 5 38,400
F.H. 8 5 38,400
F.H. 8 5 38,400
6 5 / 8 F.H. 8 1 / 4 4 3 / 4 44,600
F.H. 8 1 / 4 4 3 / 4 44,600
F.H. 8 1 / 4 4 3 / 4 44,600
F.H. 8 1 / 2 4 1 / 4 56,100
F.H. 8 1 / 2 4 1 / 4 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 Class 2
Box Make-Up Box Make-up
OD Torque OD Torque
(in) (ft-lb) (in) (ft-lb)
5 15 / 32 12,300 5 3 / 8 10,000
5 3 / 8 12,100 5 9 / 32 10,100
5 9 / 16 16,400 5 7 / 16 13,500
5 5 / 8 17,800 5 15 / 32 14,200
5 13 / 32 12,100 5 5 / 16 9,900
5 19 / 32 16,500 5 15 / 32 13,500
5 25 / 32 21,200 5 5 / 8 17,300
5 23 / 32 19,600 5 9 / 16 15,800
5 29 / 32 16,600 5 25 / 32 13,200
5 23 / 32 11,600 5 21 / 32 10,000
5 13 / 16 14,100 5 23 / 32 11,600
5 15 / 16 17,500 5 27 / 32 14,900
6 7 / 32 25,500 6 1 / 16 21,000
5 7 / 8 15,800 5 25 / 32 13,300
6 1 / 32 20,200 5 29 / 32 16,700
6 3 / 32 21,900 5 31 / 32 18,400
6 3 / 16 24,700 6 1 / 32 22,000
6 5 / 16 27,500 6 3 / 16 22,900
6 21 / 32 25,500 6 1 / 2 20,200
6 23 / 32 27,700 6 9 / 16 22,300
6 15 / 16 35,500 6 3 / 4 28,800
6 17 / 32 21,300 6 7 / 16 18,200
6 9 / 16 22,300 6 15 / 32 19,200
6 5 / 8 24,500 6 1 / 2 20,300
6 23 / 32 27,650 6 19 / 32 23,350
6 25 / 32 29,900 6 5 / 8 24,500
6 25 / 32 29,900 6 11 / 16 26,560
7 1 / 32 39,000 6 27 / 32 32,100
7 1 / 32 39,000 6 7 / 8 33,200
7 7 / 16 26,800 7 3 / 8 24,100
7 1 / 2 29,500 7 13 / 32 25,500
7 5 / 8 35,100 7 1 / 2 29,500
7 11 / 16 38,000 7 9 / 16 32,300
7 11 / 16 38,000 7 19 / 32 33,700
7 3 / 4 40,900 7 21 / 32 36,500
7 29 / 32 48,200 7 25 / 32 42,300
8 52,700 7 27 / 64 45,200
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

Performance Properties of
Seamless Drill Pipe
Cross Polar
Wall Sectional Sectional
Size Nominal Thick Area Modulus
OD Weight ness ID of Pipe Z
New Drill Pipe Dimensional, Torsional, and Tensile Data
Torsional Yield Strength (ft-lb) Tensile Yield Strength (lb)
(in) (lb/ft) (in) (in) (sq. in) (cu in) E75 X95 G105 S135 E75 X95 G105 S135
2 3 / 8 4.85 0.190 1.995 1.3042 1.320 4,760 6,020 6,060 - 97,820 123,900 136,940 176,070
6.65 0.280 1.815 1.8429 1.734 6,240 7,900 8,740 - 138,220 175,080 193,500 248,790
6.85 0.217 2.441 1.8120 2.242 8,070 10,220 11,300 - 135,900 172,140 190,260 244,620
-
10.40 0.362 2.151 2.8579 3.204 11,530 14,610 16,150 20,760 214,340 271,500 300,080 385,820
2 7 / 8 3 1 / 2 9.50 0.254 2.992 2.5902 3.922 14,120 17,890 19,770 25,420 194,260 246,070 271,970 349,680
13.30 0.368 2.764 3.6209 5.144 18,520 23,460 25,930 33,330 271,570 343,990 380,190 488,820
15.50 0.449 2.602 4.3037 5.846 21,050 26,660 29,470 37,890 322,780 408,850 451,890 581,000
4 11.85 0.262 3.476 3.0767 5.400 19,440 24,620 27,220 34,990 230,750 292,290 323,050 415,360
14.00 0.330 3.340 3.8048 6.458 23,250 29,450 32,550 41,840 285,360 361,460 399,500 513,650
15.70 0.380 3.240 4.3216 7.156 25,760 32,630 36,070 46,380 324,150 410,590 453,810 583,420
4 1 / 2 13.75 0.271 3.958 3.6004 7.184 25,860 32,760 36,210 46,550 270,030 342,040 378,050 486,060
16.60 0.337 3.826 4.4074 8.542 30,750 38,950 43,050 55,350 330,560 418,700 462,780 595,000
20.00 0.430 3.640 5.4981 10.232 36,840 46,660 51,570 66,300 412,360 522,320 577,300 742,240
5 19.50 0.362 4.276 5.2746 11.416 41,090 52,050 57,530 73,970 395,600 501,090 553,830 712,070
25.60 0.500 4.000 7.0686 14.490 52,160 66,070 73,030 93,900 530,140 671,520 742,200 954,260
5 1 / 2 21.90 0.361 4.778 5.8282 14.062 50,620 64,120 70,870 91,120 437,120 553,680 611,960 786,810
24.70 0.415 4.670 6.6296 15.688 56,470 71,530 79,060 101,650 497,220 629,810 696,110 895,000
5 7 / 8 23.40 0.361 5.153 6.2535 16.251 58,600 74,200 82,000 105,500 469,000 594,100 656,600 844,200
26.30 0.415 5.045 7.1185 18.165 65,500 83,000 91,700 117,900 533,900 676,300 747,400 961,000
6 5 / 8 25.20 0.330 5.965 6.5262 19.572 70,550 89,360 98,770 127,044 489,460 619,990 685,250 881,044
27.70 0.362 5.901 7.1226 21.156 76,300 96,600 106,800 137,300 534,200 676,700 747,900 961,600
6

New Drill Pipe Collapse and
Internal Pressure Data
Size Nominal
OD Weight
(in) (lb)
Collapse Pressure, psi
Internal Pressure, psi
E75 X95 G105 S135 E75 X95 G105 S135
2 3 / 8 4.85 11,040 13,980 15,460 19,070 10,500 13,300 14,700 18,900
6.65 15,600 19,760 21,840 28,080 15,470 19,600 21,660 27,850
2 7 / 8 6.85 10,470 12,930 14,010 17,060 9,910 12,550 13,870 17,830
10.40 16,510 20,910 23,110 29,720 16,530 20,930 23,140 29,750
3 1 / 2 9.50 10,040 12,060 13,050 15,780 9,520 12,070 13,340 17,150
13.30 14,110 17,880 19,760 25,400 13,800 17,480 19,320 24,840
15.50 16,770 21,250 23,480 30,190 16,840 21,330 23,570 30,310
4 11.85 8,410 9,960 10,700 12,650 8,600 10,890 12,040 15,480
14.00 11,350 14,380 15,900 20,170 10,830 13,720 15,160 19,490
15.70 12,900 16,340 18,050 23,210 12,470 15,790 17,460 22,440
4 1 / 2 13.75 7,200 8,400 8,950 10,310 7,900 10,010 11,070 14,230
16.60 10,390 12,750 13,820 16,800 9,830 12,450 13,760 17,690
20.00 12,960 16,420 18,150 23,330 12,540 15,890 17,560 22,580
5 19.50 10,000 12,010 12,990 15,700 9,500 12,040 13,300 17,110
25.60 13,500 17,100 18,900 24,300 13,120 16,620 18,380 23,620
5 1 / 2 21.90 8,440 10,000 10,740 12,710 8,610 10,910 12,060 15,510
24.70 10,460 12,920 14,000 17,050 9,900 12,540 13,860 17,830
5 7 / 8 23.40 7,450 8,770 9,360 10,820 8,060 10,220 11,290 14,520
26.30 9,560 11,500 12,410 14,890 9,270 11,740 12,980 16,690
6 5 / 8 25.20 4,810 5,310 5,490 6,040 6,540 8,280 9,150 11,770
27.70 5,890 6,750 7,100 7,810 7,170 9,080 10,040 12,910
7

Tool Joint Bevel Diameters
Type Size OD Bev. Dia
2 3 / 8 & N.C 26 3 3 / 8 3 17 / 64
2 7 / 8 & N.C 31 4 1 / 8 3 61 / 64
3 1 / 2 & N.C 38 4 3 / 4 4 37 / 64
Internal
Flush
&
Numbered
Connections
3 1 / 2 & 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 6 3 / 8 6 1 / 16
4 1 / 2 & N.C. 50 6 1 / 2 6 1 / 16
4 1 / 2 & N.C. 50 6 5 / 8 6 1 / 16
Full Hole
&
Numbered
Connections
N.C. 56 7 6 47 / 64
3 1 / 2 4 5 / 8 4 31 / 64
4 & N.C. 40 5 1 / 4 5 1 / 64
4 1 / 2 6 5 23 / 32
5 1 / 2 7 6 23 / 32
5 1 / 2 7 1 / 4 6 23 / 32
5 1 / 2 7 1 / 2 7 3 / 32
Xtra Hole &
Numbered
Connections
H-90
Slimline
H-90
Slimhole
&
Numbered
Connections
3 1 / 2 4 3 / 4 4 17 / 32
4 1 / 2 & N.C. 46 6 5 23 / 32
5 & N.C. 50 6 1 / 4 5 59 / 64
4 5 1 / 2 5 17 / 64
4 1 / 2 6 5 23 / 32
2 3 / 8 3 1 / 4 3 1 / 8
2 7 / 8 3 7 / 8 3 23 / 32
3 1 / 2 4 5 / 8 4 7 / 16
2 3 / 8 2 7 / 8 2 25 / 32
2 7 / 8 & N.C. 26 3 3 / 8 3 17 / 64
3 1 / 2 & N.C. 31 4 1 / 8 3 61 / 64
4 4 1 / 2 4 11 / 32
4 4 5 / 8 4 11 / 32
4 1 / 2 & N.C. 38 5 4 37 / 64
8

Decimal and Millimeter Equivalents
Fraction Decimal mm Fraction Decimal mm
1 / 64 0.015625 0.397 33 / 64 0.515625 13.097
1 / 32 0.03125 0.794 17 / 32 0.53125 13.494
3 / 64 0.046875 1.191 35 / 64 0.546875 13.891
1 / 16 0.0625 1.588 9 / 16 0.5625 14.288
5 / 64 0.078125 1.984 37 / 64 0.578125 14.684
3 / 32 0.09375 2.381 19 / 32 0.59375 15.081
7 / 64 0.109375 2.778 39 / 64 0.609375 15.478
1 / 8 0.1250 3.175 5/8 0.6250 15.875
9 / 64 0.140625 3.572 41 / 64 0.640625 16.272
5 / 32 0.15625 3.969 21 / 32 0.65625 16.669
11 / 64 0.171875 4.366 43 / 64 0.671875 17.066
3 / 16 0.1875 4.763 11 / 16 0.6875 17.463
13 / 64 0.203125 5.159 45 / 64 0.703125 17.859
7 / 32 0.21875 5.556 23 / 32 0.71875 18.256
15 / 64 0.234375 5.953 47 / 64 0.734375 18.653
1 / 4 0.2500 6.350 3 / 4 0.7500 19.050
17 / 64 0.265625 6.747 49 / 64 0.765625 19.447
9 / 32 0.28125 7.144 25 / 32 0.78125 19.844
19 / 64 0.296875 7.541 51 / 64 0.796875 20.241
5 / 16 0.3125 7.938 13 / 16 0.8125 20.638
21 / 64 0.328125 8.334 53 / 64 0.828125 21.034
11 / 32 0.34375 8.731 27 / 32 0.84375 21.431
23 / 64 0.359375 9.128 55 / 64 0.859375 21.828
3 / 8 0.3750 9.525 7 / 8 0.8750 22.225
25 / 64 0.390625 9.922 57 / 64 0.890625 22.622
13 / 32 0.40625 10.319 29 / 32 0.90625 23.019
27 / 64 0.421875 10.716 59 / 64 0.921875 23.416
7 / 16 0.4375 11.113 15 / 16 0.9375 23.813
29 / 64 0.453125 11.509 61 / 64 0.953125 24.209
15 / 32 0.46875 11.906 31 / 32 0.96875 24.606
31 / 64 0.484375 12.303 63 / 64 0.984375 25.003
1 / 2 0.5000 12.700 1 1.000 25.400
1 mm = 0.03937 inch
0.001 inch = 0.0254 mm
9

Conversion of Customary Units
to SI/Metric Units
Basic Customary SI/Metric Conversion
Unit Units Units Customary to
(Abbreviation) (Abbreviation) SI/Metric
Multiply by
Length in mm 25.4
Area sq in mm 2 645.16
Volume, capacity cu ft m 3 0.028317
U.K. gal L 4.546092
U.S. gal L 3.785412
Plane angle deg ( 0 ) rad 0.017453
Time min S 60
Mass lbm kg 0.453592
Temperature (traditional) 0 F 0 C ( 0 F-32)
Pressure lbf/in 2 (psi) bar
1.8
0.068947
N/m 2 Pa 1.
at (kp/cm 2 ) bar 1.0197
bar Pa 10 5
Density (liquids) lbm/U.S. gal kg/m 3 119.8264
lbm/U.K. gal kg/m 3 99.77633
lbm/ft kg/m 3 16.01846
Density (solids) lbm/ft 3 kg/m 3 16.01846
Throughput (mass basis) lbm/hr kg/h 0.453592
Throughput (volume basis) bbl/D m 3 /h 0.006624
ft 3 /D m 3 /h 0.001179
U.K. gal/min L/min 4.546092
U.S. gal/min L/min 3.785412
Flow rate (volume basis) U.K. gal/min L/min 4.546092
U.S. gal/min L/min 3.785412
ft 3 /min m 3 /min 0.028314
Energy work Btu kWh 0.000293
ft-lbf kJ 0.001356
lbf-ft kJ 0.001356
K N-m kJ 1.
Power hydraulic horse kW 0.746043
power-hhp
hp (electric) kW 0.746
Btu/hr W 0.293071
Fuel consumption mile/U.S. gal km/L 0.425144
mile/U.K. gal km/L 0.354066
Velocity (linear) speed ft/min m/s 0.005080
in/s mm/s 25.4
Rotational frequency rev/s rev/s 1.0
rev/min rev/s 0.016666
Weight/length lb/ft kg/m 1.488164
Force lbf N 4.448222
kg-m/sec 2 N 1.
Bending moment torque lbf-ft Nm 1.355818
Section modulus cu in mm 3 2831685
Stress kgf/mm 2 N/mm 2 9.806650
lbf/in 2 (psi) N/mm 2 0.006895
10

Drill Pipe with
Double Shoulder Connections
Box
Hardbanding
Pipe
Tool Joint
External Upset
Weld
Pin
Elevator Shoulder
Internal Upset
Internal Coating
DOUBLE
SHOULDER
CONNECTIONS
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

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 (XT-
M) – 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
12
XT

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)
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
13
Pin
ID
(in)
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
Note: Applies to drill pipe and HWDP tool joints.
Make-up
Torque
(ft-lb)
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

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)
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
Note: Applies to drill pipe and HWDP tool joints.
14
Pin
ID
(in)
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
XT
Make-up
Torque
(ft-lb)
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

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)
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
Note: Applies to drill pipe and HWDP tool joints.
Pin
ID
(in)
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
XT-M
Make-up
Torque
(ft-lb)
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
15

GPDS Tool Joint Make-up
Torque Chart
Recommended Maximum
Type
Connection
Box
OD
(in)
Pin
ID
(in)
Make-up
Torque
(ft-lb)
GPDS26
GPDS31
GPDS38
GPDS40
GPDS46
GPDS50
GPDS55
GPDS65
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
Note: Applies to drill pipe and HWDP tool joints.
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
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
Tripping
Contact of sharp edge of
pin thread on box flank
• 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 2 3
Pin
1 2 3
Box
1 2 3
1 2 3
26

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

Field Inspection Drawing, Pin
Pin
Length
Pin Cylinder
Dia
Thread Form
Nose
Dia
Bevel
Dia
30

HT Field Inspection
Dimensions, Pin
Connection
2 3/8 HTSLH90
2 7/8 HTPAC
HT26
HT31
HT38
HT40
HT46
HT50
HT55
HT65
Thread
Form
90°V 084
V 076S
V 038R
V 038R
V 038R
V 038R
V 038R
V 038R
V 050
V 050
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
31

XT ® Field Inspection
Dimensions, Pin
Connection
XT24
XT26
XT29
XT30
XT31
XT34
XT38
XT39
XT40
XT43
XT46
XT50
XT54
XT55
XT57
XT61
XT65
XT69
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
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
32

XT-M Field Inspection
Dimensions, Pin
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
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
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
33

GPDS Field Inspection
Dimensions, Pin
Connection
GPDS26
GPDS31
GPDS38
GPDS40
GPDS46
GPDS50
GPDS55
GPDS65
Thread
Form
V 038R
V 038R
V 038R
V 038R
V 038R
V 038R
V 050
V050
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
34

Field Inspection Drawing, Box
Box Depth
C Bore
Dia
Bevel
Dia
C Bore Wall
35

HT Field Inspection
Dimensions, Box
Connection
2 3/8 HTSLH90
2 7/8 HTPAC
HT26
HT31
HT38
HT40
HT46
HT50
HT55
HT65
Thread
Form
90°V 084
V 076S
V 038R
V 038R
V 038R
V 038R
V 038R
V 038R
V 050
V050
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
36

XT ® Field Inspection
Dimensions, Box
Connection
XT24
XT26
XT29
XT30
XT31
XT34
XT38
XT39
XT40
XT43
XT46
XT50
XT54
XT55
XT57
XT61
XT65
XT69
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
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
37

XT-M Field Inspection
Dimensions, Box
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
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
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
38

GPDS Field Inspection
Dimensions, Box
Connection
GPDS26
GPDS31
GPDS38
GPDS40
GPDS46
GPDS50
GPDS55
GPDS65
Thread
Form
V 038R
V 038R
V 038R
V 038R
V 038R
V 038R
V 050
V050
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
39

40

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.
· Conventional HWDP – Developed to provide a gradual
transition from the heavy drill collar to the relatively
lightweight drill pipe.
Conventional Heavy Weight Drill Pipe
HEAVY WEIGHT
DRILL PIPE
18 0
24”
B
Elevator Upset
Diameter
C
Wear Section
Upset
Diameter
A
Nominal Size
B
Upset Diameter
D
Tool Joint OD
26”
31’
Nominal
Length
18 0 24”
41

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
C
Center
Spiral Upset
26”
26”
31’
Nominal
Length
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”
C
Spiral
Upset
31’
Nominal
Length
21’4”
A
Nominal
Size
11”
D
Pin Tool
Joint
24”
43

Dimensional Data - Range II
Nominal Tube
Dimensions
Conventional Heavy Weight Drill Pipe
Tube Tool Joint Weight (lb)
Cen. End
Mechanical
Properties Tube
Mechanical
Properties
Tool Joint
Approx.
Incl. Tube &
Tool Joints
S Upset Upset
Nominal Wall Section Dia. Dia. Tensile Torsional Connection OD Tensile Torsional Per Make-up
Size ID Thickness Area Modulus [C] [B] Yield Yield Size and [D] ID Yield Yield Per Joint Torque
(in) (in) (in) (in 2 ) (in 3 ) (in) (in) (lb) (ft-lb) Type (in) (in) (lb) (ft-lb) foot (31 ft) (ft-lb)
2 7 / 8 1 1 / 2 0.688 4.727 2.161 3 5 / 16 2 15 / 16 520,000 22,400 NC26 (2 3 / 8 IF) 3 3 / 8 1 1 / 2 357,700 6,300 17.26 535 3,800
3 1 / 2 2 1 / 16 0.719 6.282 3.702 4 3 7 / 8 345,400 19,600 NC38 (3 1 / 2 IF) 4 3 / 4 2 1 / 8 842,400 19,200 25.65 795 11,500
NC38 (3 1 / 2 IF) 4 3 / 4 790,900 19,200 23.48 728 11,500
HT38 4 7 /8 790,900 34,200 23.96 743 20,500
3 1 / 2 2 1 / 4 0.625 5.645 3.490 4 3 7 / 8 310,500 18,500 2 1 / 4 XT39 4 7 / 8 871,400 40,700 23.96 743 24,400
4 2 9 / 16 0.719 7.411 5.225 4 1 / 2 4 3 / 16 407,600 27,600 NC40 (4 FH) 5 1 / 4 2 9 / 16 838,300 27,800 29.92 928 14,600
XT39 4 7 / 8 729,700 37,000 28.40 880 22,200
4 1 / 2 2 3 / 4 0.875 9.965 7.698 5 4 11 / 16 548,100 40,700 NC46 (4 IF) 6 1 / 4 2 13 / 16 1,151,100 43,600 41.45 1,285 22,500
5 3 1.000 12.566 10.681 5 1 / 2 5 1 / 8 691,200 56,500 NC50 (4 1 / 2 IF) 6 5 / 8 3 1,416,200 57,800 50.38 1,562 30,000
HT50 88,800 53,300
5 1 / 2 3 1 / 4 1.125 15.463 14.342 6 5 11 / 16 850,400 75,900 5 1 / 2 FH 7 1 / 4 3 1 / 4 1,778,300 78,700 61.63 1,911 41,200
HT55 115,100 69,000
5 7 / 8 4 0.938 14.542 15.630 6 3 /8 6 799,800 82,700 XT57 7 4 1,403,100 106,200 57.42 1,780 63,700
6 5 / 8 4 1 / 2 1.063 18.574 22.476 7 1 / 8 6 5 / 16 1,021,600 118,900 6 5 / 8 FH 8 4 1 / 2 1,896,100 87,900 71.43 2,214 50,500
NOTE: 2 7/8” HWDP is manufactured integral only (non-welded).
44

Dimensional Data - Range II
Tri-Spiral TM Heavy Weight Drill Pipe
Tube Tool Joint Weight (lb)
Nominal Tube
Dimensions
Cen. End
Mechanical
Properties Tube
Mechanical
Properties
Tool Joint
Approx.
Incl. Tube &
Tool Joints
S Upset Upset
Nominal Wall Section Dia. Dia. Tensile Torsional Connection OD Tensile Torsional Per Make-up
Size ID Thickness Area Modulus [C] [B] Yield Yield Size and [D] ID Yield Yield Per Joint Torque
(in) (in) (in) (in 2 ) (in 3 ) (in) (in) (lb) (ft-lb) Type (in) (in) (lb) (ft-lb) foot (31 ft) (ft-lb)
2 7 / 8 1 1 / 2 0.688 4.727 2.161 3 5 / 16 2 15 / 16 520,000 22,400 NC26 (2 3 / 8 IF) 3 3 / 8 1 1 / 2 357,700 6,300 18.22 565 3,800
3 1 / 2 2 1 / 16 0.719 6.282 3.702 4 3 7 / 8 345,400 19,580 NC38 (3 1 / 2 IF) 4 3 / 4 2 1 / 8 842,400 19,200 27.05 839 11,500
NC38 (3 1 / 2 IF) 4 3 / 4 790,900 19,200 24.88 771 11,500
HT38 4 7 /8 790,900 34,200 25.36 786 20,500
3 1 / 2 2 1 / 4 0.625 5.645 3.490 4 3 7 / 8 310,500 18,500 2 1 / 4 XT39 4 7 / 8 871,400 40,700 25.36 786 24,400
4 2 9 / 16 0.719 7.411 5.225 4 1 / 2 4 3 / 16 407,600 27,600 NC40 (4 FH) 5 1 / 4 2 9 / 16 838,300 27,800 31.51 977 14,600
XT39 4 7 / 8 729,700 37,000 29.99 930 22,200
4 1 / 2 2 3 / 4 0.875 9.965 7.698 5 4 11 / 16 548,100 40,700 NC46 (4 IF) 6 1 / 4 2 13 / 16 1,151,100 43,600 43.31 1,343 22,500
5 3 1.000 12.566 10.681 5 1 / 2 5 1 / 8 691,200 56,500 NC50 (4 1 / 2 IF) 6 5 / 8 3 1,416,200 57,800 52.34 1,623 30,000
HT50 88,800 53,300
5 1 / 2 3 1 / 4 1.125 15.463 14.342 6 5 11 / 16 850,400 75,900 5 1 / 2 FH 7 1 / 4 3 1 / 4 1,778,300 78,700 63.78 1,977 41,200
HT55 115,100 69,000
5 7 / 8 4 0.938 14.542 15.630 6 3 /8 6 799,800 82,700 XT57 7 4 1,403,100 106,200 57.42 1,780 63,700
6 5 / 8 4 1 / 2 1.063 18.574 22.476 7 1 / 8 6 5 / 16 1,021,600 118,900 6 5 / 8 FH 8 4 1 / 2 1,896,100 87,900 74.67 2,315 50,500
NOTE: 2 7/8” Tri-Spiral TM is manufactured integral only (non-welded).
45

Dimensional Data - Range II
Spiral-Wate ® Heavy Weight Drill Pipe
Tube Tool Joint Weight (lb)
Nominal Tube
Dimensions
Cen. End
Mechanical
Properties Tube
Mechanical
Properties
Tool Joint
Approx.
Incl. Tube &
Tool Joints
S Upset Upset
Nominal Wall Section Dia. Dia. Tensile Torsional Connection OD Tensile Torsional Per Make-up
Size ID Thickness Area Modulus [C] [B] Yield Yield Size and [D] ID Yield Yield Per Joint Torque
(in) (in) (in) (in 2 ) (in 3 ) (in) (in) (lb) (ft-lb) Type (in) (in) (lb) (ft-lb) foot (31 ft) (ft-lb)
3 3 / 16 2 0.594 4.840 2.687 3 5 / 16 3 3 / 16 532,400 28,400 SLH90 3 7 / 8 2
407,000 12,000 19.48 604 6,300
3 1 / 2 2 1 / 4 0.625 5.645 3.490 4 3 5 / 8 310,500 18,500 NC38 (3 1 / 2 IF) 790,900 22,900 13,100
HT38 790,900 34,200 20,500
4 7 / 8 2 1 / 4 30.39 942 XT39 871,400 40,700 24,400
4 2 9 / 16 0.719 7.411 5.225 4 1 / 2 4 1 / 8 407,600 27,600 NC40 (4 FH) 5 2 9 / 16 838,300 20,900 28.90 896 12,600
XT39 729,700 40,800 24,500
4 1 / 2 2 3 / 4 0.875 9.965 7.698 5 4 5 /8 548,100 40,700 NC46 (4 IF) 6 1 / 4 2 13 / 16 1,151,100 43,600 49.53 1,535 22,500
57,800 59.16 1,834 30,000
5 3 1.000 12.566 10.681 5 1 /2 5 1 / 8 691,200 56,500 NC50 (4 1 / 2 IF) 6 5 / 8 3 1,416,200 HT50 88,800 53,300
7 4 1,265,800 55,900 55.21 1,712 29,200
5 1 / 2 4 0.750 11,192 11.764 6 5 5 / 8 615,600 62,200 5 1 / 2 FH HT55 77,200 46,300
5 7 / 8 4 0.938 14.542 15.630 6 3 /8 6 799,800 82,700 XT57 7 4 1,403,100 106,200 65.38 2,027 63,700
6 5 / 8 5 0.813 14.837 19.285 7 1 / 8 6 3 / 4 816,000 102,000 6 5 / 8 FH 8 5
1,448,400 73,700 73.40 2,,275 38,400
NOTE: 3 3/16” Spiral-Wate TM , previously referred to as 2-7/8”, is manufactured integral only (non-welded).
46

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.
Maintenance
Use thread protectors on both connections when
handling drill collars. Alternate different joints on each
trip. Clean and inspect the individual connections.
DRILL
COLLARS
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

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
A
20”
A
R
Cold Work
Shoulder Area
B
2”
Radius
1”
Radius
Shoulder Area
C
2”
Radius
B
C
16”
3”
3”
18”
3”
48

Materials Mechanical Properties
Drill Collar Min. Min. Min.
Diameter Yield Strength Tensile Strength Hardness
(in) (psi) (psi) (BHN)
3 1 / 8 thru 6
7/ 8 110,000 140,000 285
7 thru 11 100,000 135,000 285
Slip and Elevator Recess Dimensions
Drill Elevator Slip Elevator
Collar Recess Recess Recess
Diameter Diameter Diameter Radius
A B C R
(in) (in) (in) (in)
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
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 9 1 / 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
Bore of Drill Collar (in)
Size Type OD 1 1 1 / 4 1 1 / 2
(in)
3 *2,500 *2,500 *2,500
*3390 *3390 *3390
API NC 23 3 1 / 8 *3,300 *3,300 2,600
*4474 *4474 3525
3 1 / 4 4,000 3,400 2,600
5423 *4610 3525
3 *3,800 *3,800
*5152 *5152
2 7 / 8 PAC 3 3 1 / 8 *4,900 4,200
6644 5694
3 1 / 4 5,200 4,200
7050 5694
2 3 / 8 API IF or 3 1 / 2 *4,600 *4,600
*6237 *6237
API NC 26 or 3 3 / 4 5,500 4,700
7457 6372
2 3 / 8 Slim Hole
2 7 / 8 Extra Hole or 3 3 / 4 *4,100 *4,100
*5559 *5559
3 1 / 2 Dbl. Streamline 3 7 / 8 *5,300 *5,300
or *7186 *7186
2 7 / 8 Mod. Open 4 1 / 8 *8,000 *8,000
*10847 *10847
2 7 / 8 API IF or 3 7 / 8 *4,600 *4,600
*6237 *6237
API NC 31 or 4 1 / 8 *7,300 *7,300
*9897 *9897
4 1 / 4 *8,800 *8,800
*11931 *11931
3 1 / 2 Slim Hole 4 1 / 2 10,000 9,300
13558 12609
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
3 1 / 2 Mod. Open 5
4 3 / 4
5 1 / 4
50

Bore of Drill Collar (in)
Foot-Pound
Newton-Meters
1 3 / 4 2 2 1 / 4 2 1 / 2 2 13 / 16
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 *4,600
*6237 *6237
*7,300 6,800
*9897 9220
8,100 6,800
10982 9220
8,100 6,800
10982 9220
*8,900 *8,900 *8,900 7,400
*12067 *12067 *12067 10033
12,100 *10,800 9,200 7,400
16405 14643 12474 10033
12,100 10,800 9,200 7,400
16405 14643 12474 10033
*5,100 *5,100 *5,100 *5,100
6915 6915 6915 6915
*8,400 *8,400 *8,400 *8,200
*11389 11389 11389 11118
*11,900 11,700 10,000 8,200
*16134 15863 13558 11118
13,200 11,700 10,000 8,200
17897 15863 13558 11118
13,200 11,700 10,000 8,200
17897 15863 13558 11118
51

Recommended Minimum Make-up
Torque for Rotary Shouldered Drill
Collar Connections
Connection
Bore of Drill Collar (in)
Size Type OD 1 1 1 / 4 1 1 / 2
(in)
3 1 / 2 API IF or 4 3 / 4
API NC 38 or 5
5 1 / 4
4 1 / 2 Slim Hole
5 1 / 2
4 3 / 4
3 1 / 2 H 90 4 5 1 / 4
5
4 Full Hole 5
5 1 / 2
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 90 4 5 3 / 4
6
6 1 / 4
5 1 / 2
5 3 / 4
4 1 / 2 API Regular
6
6 1 / 4
52

Foot-Pound
Newton-Meters
Bore of Drill Collar (in)
1 3 / 4 2 2 1 / 4 2 1 / 2 2 13 / 16
*9,900 *9,900 *9,900 *9,900 *8,300
13423 13423 13423 13423 *11253
*13,800 *13,800 12,800 10,900 8,300
*18710 *18710 17354 14778 11253
16,000 14,600 12,800 10,900 8,300
21693 19795 17354 14778 11253
16,000 14,600 12,800 10,900 8,300
21693 19795 17354 14778 11253
*8,700 *8,700 *8,700 *8,700 *8,700
*11796 *11796 *11796 *11796 *11796
*12,700 *12,700 *12,700 12,700 10,400
*17219 *17219 *17219 17219 14101
*16,900 16,700 15,000 13,100 10,400
*22913 22642 20337 17761 14101
18,500 16,700 15,000 13,100 10,400
25083 22642 20337 17761 14101
*10,800 *10,800 *10,800 *10,800 *10,800
*14643 *14643 *14643 *14643 *14643
*15,100 *15,100 *15,100 14,800 12,100
*20473 *20473 *20473 20066 16405
*19,700 18,600 16,900 14,800 12,100
*26710 25218 22913 20066 16405
20,400 18,600 16,900 14,800 12,100
27659 25218 22913 20066 16405
20,400 18,600 16,900 14,800 12,100
27659 25218 22913 20066 16405
*12,500 *12,500 *12,500 *12,500
*16948 *16948 *16948 *16948
*17,300 *17,300 *17,300 *16,500
*23456 *23456 *23456 22371
*22,300 21,500 19,400 16,500
*30235 *29150 26303 22371
23,500 21,500 19,400 16,500
31862 29150 26303 22371
23,500 21,500 19,400 16,500
31862 29150 26303 22371
*15,400 *15,400 *15,400 *15,400
*20880 *20880 *20880 *20880
*20,300 *20,300 19,400 16,200
*27523 *27523 26303 21964
23,400 21,600 19,400 *16,200
31726 29286 26303 21964
23,400 21,600 19,400 16,200
31726 29286 26303 21964
53

Recommended Minimum Make-up
Torque for Rotary Shouldered Drill
Collar Connections
Connection
Bore of Drill Collar (in)
Size Type OD 1 1 / 2 1 3 / 4 2
(in)
5 1 / 4 *20,600
*27930
6 25,000
API NC 44 33895
6 1 / 4 25,000
33895
6 1 / 2 25,000
33895
5 1 / 2 *12,900
*17490
5 3 / 4 *17,900
*24269
4 1 / 2 API Full Hole 6 *23,300
*31591
4 1 / 2 Extra Hole 5 3 / 4
API NC 46 6
4 API IF 6 1 / 4
4 1 / 2 Semi F 6 1 / 2
5 Dbl Streamline 6 3 / 4
4 1 / 2 Mod Open 6 3 / 4
6 1 / 4 27,000
36607
6 1 / 2 27,000
36607
5 3 / 4
6
4 1 / 2 H 90 4 6 1 / 4
6 1 / 2
6 3 / 4
6 1 / 4
6 1 / 2
5 H 90 4 6 3 / 4
7
54

Foot-Pound
Newton-Meters
Bore of Drill Collar (in)
2 1 / 4 2 1 / 2 2 13 / 16 3 3 1 / 4
*20,600 *20,600 18,000
*27930 *27930 24405
23,300 21,200 18,000
31591 28743 24405
23,300 21,200 18,000
31591 28743 24405
23,300 21,200 18,000
31591 28743 24405
*12,900 *12,900 *12,900 *12,900
*17490 *17490 *17490 *17490
*17,900 *17,900 *17,900 17,700
*24269 *24269 *24269 23998
*23,300 22,800 19,800 17,700
*31591 30913 26845 23998
*25,000 22,800 19,800 17,700
33895 30913 26845 23998
25,000 22,800 19,800 17,700
33895 30913 26845 23998
*17,600 *17,600 *17,600 *17,600
*23862 *23862 *23862 *23862
*23,200 *23,200 22,200 20,200
31455 31455 30099 27388
28,000 25,500 22,200 20,200
37963 34573 30099 27388
28,000 25,500 22,200 20,200
37963 34573 30099 27388
28,000 25,500 22,200 20,200
37963 34573 30099 27388
*17,600 *17,600 *17,600 *17,600
*23862 *23862 *23862 *23862
*23,400 *23,400 23,000 21,000
*31726 *31726 31184 28472
28,500 26,000 23,000 21,000
38641 35251 31184 28472
28,500 26,000 23,000 21,000
38641 35251 31184 28472
28,500 26,000 23,000 21,000
38641 35251 31184 28472
*25,000 *25,000 *25,000 *25,000
*33895 *33895 *33895 *33895
*31,500 *31,500 29,500 27,000
*42708 *42708 39997 36607
35,000 33,000 29,500 27,000
47453 44742 39997 36607
35,000 33,000 29,500 27,000
47453 44742 39997 36607
55

Recommended Minimum Make-up
Torque for Rotary Shouldered Drill
Collar Connections
Connection
Bore of Drill Collar (in)
Size Type OD 2 2 1 / 4 2 1 / 2
(in)
4 1 / 2 API IF or 6 1 / 4 *22,800 *22,800
*30913 *30913
API NC 50 or 6 1 / 2 *29,500 *29,500
39997 *39997
5 Extra Hole or 6 3 / 4 *36,000 35,500
*48809 48132
5 Mod Open or 7 38,000 35,500
51521 48132
5 1 / 2 Dbl. Streamline 7 1 / 4 38,000 35,500
or Semi IF 51521 48132
6 3 / 4 *34,000 *34,400
*46098 46640
7 *41,500 40,000
5 1 / 2 H 90 4 *56266 54233
7 1 / 4 42,500 40,000
57622 54233
7 1 / 2 42,500 40,000
57622 54233
6 3 / 4 *31,500 *31,500
*42708 *42708
7 *39,000 *39,000
5 1 / 2 API Regular *52877 *52877
7 1 / 4 42,000 39,500
56944 53555
7 1 / 2 42,000 39,500
56944 53555
7 *32,500
*44064
7 1 / 4 *40,500
5 1 / 2 API Full Hole *54911
7 1 / 2 *49,000
66435
7 3 / 4 51,500
69825
7 1 / 4 *40,000
54233
7 1 / 2 *48,500
API NC 56 *65757
7 3 / 4 51,000
69147
8 51,000
69147
56

Bore of Drill Collar (in)
Foot-Pound
Newton-Meters
2 13 / 16 3 3 1 / 4 3 1 / 2 3 3 / 4
*22,800 *22,800 *22,800
*30913 *30913 *30913
*29,500 *29,500 26,500
*39997 *39997 35929
32,200 30,000 26,500
43657 40675 35929
32,000 30,000 26,500
43386 40675 35929
32,000 30,000 26,500
43386 40675 35929
*34,000 34,000
*46098 46098
36,500 34,000
49487 46098
36,500 34,000
49487 46098
36,500 34,000
49487 46098
*31,500 *31,500
*42708 *42708
36,000 33,500
48809 45420
36,000 33,500
48809 45420
36,000 33,500
48809 45420
32,500 32,500 *32,500
44064 44064 *44064
*40,500 *40,000 *40,500
*54911 *54233 *54911
47,000 45,000 41,500
63723 61012 56266
47,000 45,000 41,500
63723 61012 56266
*40,000 *40,000 *40,000
*54233 *54233 *54233
48,000 45,500 42,000
65079 61690 56944
48,000 45,000 42,000
65079 61012 56944
48,000 45,000 42,000
65079 61012 56944
57

Recommended Minimum Make-up
Torque for Rotary Shouldered Drill
Collar Connections
Connection
Bore of Drill Collar (in)
Size Type OD 2 2 1 / 4 2 1 / 2
(in)
7 1 / 2 *46,000
*62368
7 3 / 4 *55,000
6 5 / 8 API Regular *74570
8 57,000
77282
8 1 / 4 57,000
77282
7 1 / 2 *46,000
*62368
7 3 / 4 *55,000
6 5 / 8 H 90 4 *74570
8 59,500
*80671
8 1 / 4 59,500
80671
8 *54,000
*73214
8 1 / 4 *64,000
*86772
API NC 61 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
5 1 / 2 API IF 100331
8 3 / 4 74,000
100331
9 74,000
100331
9 1 / 4 74,000
100331
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 3 1 / 2 3 3 / 4
*46,000 *46,000 *46,000
*62368 *62368 *62368
53,000 50,000 47,000
71858 67791 63723
53,000 50,000 47,000
71858 67791 63723
53,000 50,000 47,000
71858 67791 63723
*46,000 *46,000 *46,000
*62368 *62368 *62368
55,000 53,000 49,500
*74570 71858 67113
*56,000 53,000 49,500
*75926 71858 67113
56,000 53,000 49,500
75926 71858 67113
*54,000 *54,000 *54,000
*73214 *73214 *73214
*64,000 *64,000 61,000
*86772 *86772 82705
68,000 65,000 61,000
92196 88128 82705
68,000 65,000 61,000
92196 88128 82705
68,000 65,000 61,000
92196 88128 82705
*56,000 *56,000 *56,000 *56,000
*75926 *75926 *75926 *75926
*66,000 *66,000 63,000 59,000
*89484 *89484 85417 79993
70,000 67,000 63,000 59,000
94907 90840 85417 79993
70,000 67,000 63,000 59,000
94907 90840 85417 79993
70,000 67,000 63,000 59,000
94907 90840 85417 79993
70,000 67,000 63,000 59,000
94907 90840 85417 79993
*67,000 *67,000 *67,000 *67,000 66,500
*90840 *90840 *90840 *90840 90162
*78,000 *78,000 76,000 72,000 66,500
*105754 *105754 103042 97619 90162
83,000 80,000 76,000 72,000 66,500
112533 108465 103042 97619 90162
83,000 80,000 76,000 72,000 66,500
112533 108465 103042 97619 90162
83,000 80,000 76,000 72,000 66,500
112533 108465 103042 97619 90162
59

Recommended Minimum Make-up
Torque for Rotary Shouldered Drill
Collar Connections
Connection
Bore of Drill Collar (in)
Size Type OD 2 2 1 / 4 2 1 / 2
(in)
9
9 1 / 4
API NC 70
9 1 / 2
9 3 / 4
10
10 1 / 4
10
10 1 / 4
API NC 77 10 1 / 2
10 3 / 4
11
8
7 H 90 4 8 1 / 4
8 1 / 2
8 1 / 2
7 5 / 8 API Regular
8 3 / 4
9
9 1 / 4
9 1 / 2
9
7 5 / 8 H 90 4 9 1 / 4
9 1 / 2
60

Foot-Pound
Newton-Meters
Bore of Drill Collar (in)
2 13 / 16 3 3 1 / 4 3 1 / 2 3 3 / 4
*75,000 *75,000 *75,000 *75,000 *75,000
*101686 *101686 *101686 *101686 *101686
*88,000 *88,000 *88,000 *88,000 *88,000
*119312 *119312 *119312 *119312 *119312
*101,000 *101,000 100,000 95,000 90,000
*136938 *136938 135582 128803 122024
107,000 105,000 100,000 95,000 90,000
145073 142361 135582 128803 122024
107,000 105,000 100,000 95,000 90,000
145073 142361 135582 128803 122024
107,000 105,000 100,000 95,000 90,000
145073 142361 135582 128803 122024
*107,000 *107,000 *107,000 *107,000
*145073 *145073 *145073 *145073
*122,000 *122,000 *122,000 *122,000
*165410 *165410 *165410 *165410
*138,000 *138,000 133,000 128,000
*187103 *187103 180324 173545
143,000 138,000 133,000 128,000
193882 187103 180324 173545
143,000 138,000 133,000 128,000
193882 187103 180324 173545
*53,000 *53,000 *53,000 *53,000
*71858 *71858 *71858 *71858
*63,000 *63,000 *63,000 60,500
*85417 *85417 *85417 *82027
71,500 68,500 65,000 60,500
96941 92874 88128 82027
*60,000 *60,000 *60,000 *60,000
*81349 *81349 *81349 *81349
*71,000 *71,000 *71,000 *71,000
*96263 *96263 *96263 *96263
*83,000 *83,000 79,000 74,000
*112533 *112533 107110 100331
88,000 83,000 79,000 74,000
119312 112532 107110 100331
88,000 83,000 79,000 74,000
119312 112532 107110 100331
*72,000 *72,000 *72,000 *72,000
*97619 *97619 *97619 *97619
*85,500 *85,500 *85,500 *85,500
*115922 *115922 *115922 *115922
*98,000 *98,000 *98,000 95,500
*132870 *132870 *132870 129481
61

Recommended Minimum Make-up
Torque for Rotary Shouldered Drill
Collar Connections
Connection
Bore of Drill Collar (in)
Size Type OD 2 2 1 / 4 2 1 / 2
(in)
10
8 5 / 8 API Regular 10 1 / 4
10 1 / 2
10 1 / 4
8 5 / 8 H 90 4 10 1 / 2
7 H 90 4 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
(with low
10 1 / 4
7 5 / 8 H 90 4
torque face)
10 1 / 2
8 5 / 8 API Regular 10 3 / 4
(with low
torque face)
11
8 5 / 8 H 90 4 11
10 3 / 4
(with low
torque face)
11 1 / 4
*NOTE 1:
NOTE 2:
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.
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

Bore of Drill Collar (in)
Foot-Pound
Newton-Meters
2 13 / 16 3 3 1 / 4 3 1 / 2 3 3 / 4
*108,000 *108,000 *108,000 *108,000
*146428 *146428 *146428 *146428
*123,000 *123,000 *123,000 *123,000
*166766 *166766 *166766 *166766
139,000 134,000 129,000 123,000
188459 181680 174901 166766
*112,500 *112,500 *112,500 *112,500
*152530 *152530 *152530 *152530
*128,500 *128,500 *128,500 *128,500
*174223 *174223 *174223 *174223
*67,500 *67,500 66,500 62,000
*91518 *91518 90162 84061
74,000 71,000 66,500 62,000
100331 96263 90162 84061
*72,000 *72,000 *72,000 *72,000
*97619 *97619 *97619 *97619
*85,000 *85,000 82,000 77,000
*115245 *115245 111177 104398
91,000 87,000 82,000 77,000
123379 117956 111177 104398
91,000 87,000 82,000 77,000
123379 117956 111177 104398
*91,000 *91,000 *91,000 *91,000
*123379 *123379 *123379 *123379
*105,000 *105,000 103,500 98,000
*142361 *142361 140327 132870
112,500 108,000 103,500 98,000
152530 146428 140327 132870
112,500 108,000 103,500 98,000
152530 146428 140327 132870
*112,000 *112,000 *112,000 *112,000
*151852 *151852 *151852 *151852
*129,000 *129,000 *129,000 *129,000
*174901 *174901 *174901 *174901
*92,500 *92,500 *92,500 *92,500
*125413 *125413 *125413 *125413
*110,000 *110,000 *110,000 *110,000
*149140 *149140 *149140 *149140
*128,000 *128,000 *128,000 *128,000
*173545 *173545 *173545 *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 2 7 / 8 PAC connection is based on 87,500 psi stress and other
factors listed in footnote 1 .
4 Make-up torque for H-90 connection is based on 56,200 psi stress and other
factors listed in footnote 1 .
63

Groove Machining For
Elevators and Slips
DRILL ELEVATOR SLIP
COLLAR OD GROOVE DIA GROOVE DIA RADIUS
A B + - 1/64 C + - 1/32 R
4 1/8
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
3 11/16
4 1/4
4 1/2
4 3/4
5
5 1/8
5 3/8
5 5/8
5 7/8
6
6 1/4
6 1/2
6 3/4
7
7 1/4
7 1/2
7 3/4
8 1/8
8 5/8
8 7/8
9 1/8
10 1/8
3 3/4
4 3/8
4 5/8
4 7/8
5 1/8
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 1/2
9
9 1/4
9 1/2
10 1/2
1/8
1/8
1/8
1/8
1/8
1/8
1/8
1/8
1/8
3/16
3/16
3/16
3/16
3/16
3/16
3/16
3/16
1/4
1/4
1/4
1/4
1/4
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
64

Hardbanding
65

Drill Collar Weight
lb/ft, kg/m
Drill Collar
OD
Drill Collar ID (in)
(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
2 7 / 8 19 18 16
28 27 24
3 21 20 18
31 30 27
3 1 / 8 22 22 20
33 33 30
3 1 / 4 26 24 22
39 36 33
3 1 / 2 30 29 27
45 43 40
3 3 / 4 35 33 32
52 49 48
4 40 39 37 35 32 29
60 58 55 52 48 43
4 1 / 8 43 41 39 37 35 32
64 61 58 55 52 48
4 1 / 4 46 44 42 40 38 35
68 65 62 60 56 52
4 1 / 2 51 50 48 46 43 41
76 74 71 68 64 61
4 3 / 4 54 52 50 47
80 77 74 70
5 61 59 56 53
91 88 83 79
5 1 / 4 68 65 63 60
101 97 94 89
5 1 / 2 75 73 70 67
112 108 104 100
5 3 / 4 82 80 78 75
122 119 116 112
6 90 88 85 83
134 131 126 124
6 1 / 4 98 96 94 91
146 143 140 135
6 1 / 2 107 105 102 99
159 156 152 147
6 3 / 4 116 114 111 108
172 170 165 161
7 125 123 120 117
186 183 179 174
7 1 / 4 134 132 130 127
199 196 193 189
7 1 / 2 144 142 139 137
214 211 207 204
7 3 / 4 154 152 150 147
229 226 223 218
66

Pound per foot
Kilogram per meter
2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
44
65
50
74
57
85
64 60
95 89
72 67 64 60
107 100 95 89
79 75 72 68
118 111 107 101
88 83 80 76 72
131 123 119 113 107
96 91 89 85 80
143 135 132 126 119
105 100 98 93 89
156 149 146 138 132
114 110 107 103 98 93 84
170 163 159 153 146 138 125
124 119 116 112 108 103 93
184 177 172 166 161 153 138
133 129 126 122 117 113 102
198 192 187 181 174 168 152
144 139 136 132 128 123 112
214 207 202 196 190 183 166
67

Drill Collar Weight
lb/ft, kg/m
Drill Collar
Drill Collar ID (in)
OD
(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
8 165 163 160 157
245 242 238 233
8 1/4 176 174 171 168
262 257 254 250
8 1/2 187 185 182 179
278 275 270 266
9 210 208 206 203
312 309 306 302
9 1/2 234 232 230 227
348 345 342 337
9 3/4 248 245 243 240
369 364 361 357
10 261 259 257 254
388 385 382 377
11 317 315 313 310
471 468 465 461
12 379 377 374 371
563 560 557 551
Note 1: Refer to API Spec. 7 Latest Edition for API standard drill collar
dimensions.
31ft (lb), 31 ft (kg)
Drill Collar
Drill Collar ID (in)
OD
(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
2 7/8 589 558 496
267 253 225
3 651 620 558
295 281 253
3 1/8 682 682 620
309 309 281
3 1/4 806 744 682
365 337 309
3 1/2 930 899 837
422 407 400
3 3/4 1,085 1,023 992
492 463 450
4 1,240 1,209 1,147 1,085 992 899
562 548 520 492 450 407
4 1/8 1,333 1,271 1,209 1,147 1,085 992
604 577 548 520 492 450
4 1/4 1,426 1,364 1,302 1,240 1,178 1,085
647 619 590 562 534 492
68

Pound per foot
Kilogram per meter
2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
154 150 147 143 138 133 122
229 223 218 213 205 198 181
165 160 158 154 149 144 133
245 238 235 229 221 214 198
176 172 169 165 160 155 150
262 256 251 245 238 230 223
200 195 192 188 184 179 174
297 290 285 279 273 266 259
224 220 216 212 209 206 198
333 327 321 315 311 306 294
237 232 229 225 221 216 211
352 345 340 334 328 321 314
251 246 243 239 235 230 225
373 366 361 355 349 342 334
307 302 299 295 291 286 281
456 449 444 438 432 425 418
368 364 361 357 352 347 342
547 541 537 531 523 516 508
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 3 1/2 3 3/4 4
69

Drill Collar Weight
31ft(lb), 31ft(kg)
Drill Collar
OD
Drill Collar ID (in)
(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
4 1/2 1,581 1,550 1,488 1,426 1,333 1,271
717 703 675 646 604 576
4 3/4 1,674 1,612 1,550 1,457
759 731 703 660
5 1,891 1,829 1,736 1,643
857 829 787 745
5 1/4 2,108 2,015 1,953 1,860
956 913 885 843
5 1/2 2,325 2,263 2,170 2,077
1,055 1,026 984 942
5 3/4 2,542 2,480 2,418 2,325
1,152 1,125 1,097 1,055
6 2,790 2,728 2,635 2,573
1,266 1,237 1,195 1,167
6 1/4 3,038 2,976 2,914 2,821
1,378 1,350 1,322 1,280
6 1/2 3,317 3,255 3,162 3,069
1,505 1,476 1,434 1,392
6 3/4 3,596 3,534 3,441 3,348
1,631 1,603 1,561 1,519
7 3,875 3,813 3,720 3,627
1,758 1,730 1,687 1,645
7 1/4 4,154 4,092 4,030 3,937
1,884 1,856 1,828 1,786
7 1/2 4,464 4,402 4,309 4,247
2,025 1,997 1,955 1,926
7 3/4 4,774 4,712 4,650 4,557
2,165 2,137 2,109 2,067
8 5,115 5,053 4,960 4,867
2,320 2,292 2,250 2,208
8 1/4 5,456 5,394 5,301 5,208
2,475 2,447 2,404 2,362
8 1/2 5,797 5,735 5,642 5,549
2,629 2,601 2,559 2,517
9 6,510 6,448 6,386 6,293
2,953 2,925 2,897 2,854
9 1/2 7,254 7,192 7,130 7,037
3,290 3,262 3,234 3,192
9 3/4 7,688 7,595 7,533 7,440
3,487 3,445 3,417 3,375
10 8,091 8,029 7,967 7,874
3,670 3,642 3,614 3,572
11 9,827 9,765 9,703 9,610
4,457 4,429 4,401 4,359
12 11,749 11,687 11,594 11,501
5,329 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 3 3/4 4
1,364
618
1,550
703
1,767
801
1,984 1,860
899 843
2,232 2,077 1,984 1,860
1,012 942 899 843
2,449 2,325 2,232 2,108
1,111 1,055 1,012 956
2,728 2,573 2,480 2,356 2,232
1,237 1,167 1,125 1,069 1,012
2,976 2,821 2,759 2,635 2,480
1,350 1,280 1,251 1,195 1,125
3,255 3,100 3,038 2,883 2,759
1,476 1,406 1,378 1,308 1,252
3,534 3,410 3,317 3,193 3,038 2,883 2,604
1,603 1,547 1,505 1,448 1,378 1,308 1,181
3,844 3,689 3,596 3,472 3,348 3,193 2,883
1,744 1,673 1,631 1,575 1,519 1,448 1,308
4,123 3,999 3,906 3,782 3,627 3,503 3,162
1,870 1,814 1,772 1,715 1,645 1,589 1,434
4,464 4,309 4,216 4,092 3,968 3,813 3,472
2,024 1,955 1,912 1,856 1,800 1,730 1,575
4,774 4,650 4,557 4,433 4,278 4,123 3,782
2,165 2,109 2,067 2,011 1,940 1,870 1,715
5,115 4,960 4,898 4,774 4,619 4,464 4,123
2,320 2,250 2,222 2,165 2,095 2,025 1,870
5,456 5,332 5,239 5,115 4,960 4,805 4,650
2,475 2,419 2,376 2,320 2,250 2,180 2,109
6,200 6,045 5,952 5,828 5,704 5,549 5,394
2,812 2,742 2,700 2,644 2,587 2,517 2,447
6,944 6,820 6,696 6,572 6,479 6,386 6,138
3,150 3,093 3,037 2,981 2,939 2,897 2,784
7,347 7,192 7,099 6,975 6,851 6,696 6,541
3,333 3,262 3,220 3,164 3,108 3,037 2,967
7,781 7,626 7,533 7,409 7,285 7,130 6,975
3,529 3,459 3,417 3,361 3,304 3,234 3,164
9,517 9,362 9,269 9,145 9,021 8,866 8,711
4,317 4,247 4,204 4,148 4,092 4,022 3,951
11,408 11,284 11,191 11,067 10,912 10,757 10,602
5,175 5,118 5,076 5,020 4,950 4,879 4,809
71

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
Size
Numbered
Connection (NC)
Internal Flush
(IF)
Slim Hole
(SH)
Full Hole
(FH)
26
2 3/8
2 7/8
31
2 7/8
3 1/2
Double Streamline
(DSL)
Extra Hole
(XH)
3 1/2
2 7/8
External Flush
(EF)
86

38
40 46 50
3 1/2
4
4 1/2
4
4 1/2
4
4 1/2
5 1/2
3 1/2
4 1/2 5
4 1/2
87

Ideal Drill Collar Range
Casing Size Ideal Drill
Hole Size To Be Run
(in) (in) Min.
(in)
6 1 / 8 4 1 / 2 3.875
6 1 / 4 4 1 / 2 3.750
6 3 / 4 4 1 / 2 3.250
4 1 / 2 2.125
7 7 / 8
5 1 / 2 4.225
5 1 / 2 3.725
8 3 / 8
6 5 / 8 6.405
6 5 / 8 6.280
8 1 / 2
7 *6.812
6 5 / 8 6.030
8 3 / 4
7 6.562
7 6.812
9 1 / 2
7 5 / 8 7.500
7 5.437
9 7 / 8
7 5 / 8 7.125
10 5 / 8
7 5 / 8 6.375
8 5 / 8 *8.625
11 8 5 / 8 8.250
12 1 / 4
9 5 / 8 9.000
10 3 / 4 *11.250
13 3 / 4 10 3 / 4 9.750
14 3 / 4 11 3 / 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
* 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
Max.
(in)
API Drill Collar
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 JAW CAPACITY APPLICABLE API
TYPE SIZES (in) (ft-lbs.) DRILL COLLAR SIZES (in)
B.J. HUGHES COMPANY
SXD 8 - 16 200,000 8, 8 1 / 4, 9, 9 1 / 2, 9 3 / 4, 10, 11
SDD 4 - 12 100,000 4 1 / 8, 4 3 / 4, 5, 6, 6 1 / 4, 6 1 / 2,
6 3 / 4, 7, 7 1 / 4, 7 3 / 4, 8, 8 1 / 4, 9,
9 1 / 2, 9 3 / 4, 10
DB 3 1 / 2 - 11 1 / 4 65,000 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6, 6 1 / 4, 6 1 / 2,
6 3 / 4, 7, 7 1 / 4, 7 3 / 4, 8, 8 1 / 4
B 3 1 / 2 - 9 55,000 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6, 6 1 / 4, 6 1 / 2,
6 3 / 4, 7, 7 1 / 4, 7 3 / 4, 8
C 2 3 / 8 - 10 3 / 4 35,000 3 1 / 8, 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6,
6 1 / 4, 6 1 / 2, 6 3 / 4
F 2 3 / 8 - 10 3 / 4 25,000 3 1 / 8, 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6
JOY-WEB WILSON COMPANY
ST-160 7 1 / 2 - 12 160,000 7 3 / 4, 8, 8 1 / 4, 9, 9 1 / 2, 9 3 / 4,
10 11
ST-60 4 - 9 5 / 8 60,000 4 1 / 8, , 4 3 / 4, 5, 6, 6 1 / 4, 6 1 / 2,
6 3 / 4, 7, 7 1 / 4, 7 3 / 4, 8
H 3 1 / 2 - 10 3 / 4 80,000 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6, 6 1 / 4,
6 1 / 2, 7, 7 1 / 4, 7 3 / 4, 8, 8 1 / 4, 9
AAX 2 7 / 8 - 7 1 / 4 55,000 3 1 / 8, 3 1 / 2, 4 1 / 8, , 4 3 / 4, , 5, 6,
6 1 / 4, 6 1 / 2, 6 3 / 4, 7, 7 1 / 4, 8
B 2 3 / 8 - 8 5 / 8 35,000 3 1 / 8, 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6,
6 1 / 4, 6 1 / 2, 6 3 / 4
WOOLLEY COMPANY
SDD 4 - 12 100,000 4 1 / 8, 4 3 / 4, 5, 6, 6 1 / 4, 6 1 / 2,
6 3 / 4, 7, 7 1 / 4, 7 3 / 4, 8, 8 1 / 4,
9, 9 1 / 2, 9 3 / 4, 10
SUPER A 3 1 / 2 - 11 1 / 4 65,000 3 1 / 2, , 4 1 / 4, 4 3 / 4 , 5, 6, 6 1 / 4,
6 1 / 2, 6 3 / 4, 7, 7 1 / 4, 7 3 / 4, 8, 8 1 / 4
SUPER B
1
/ 2 - 9 55,000 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6, 6 1 / 4, 6 1 / 2,
7, 7 1 / 4, 8
SUPER C 2 3 / 8 - 7 35,000 3 1 / 8, 3 1 / 2, 4 1 / 8, 4 3 / 4, 5, 6,
6 1 / 4, 6 1 / 2, 6 3 / 4
90

Kellys
KELLYS
91

Kelly Weights Pounds Per Foot
(Drive Section)
Square Kelly
Bore of Square Kelly
Across
Flat 1 1 / 16 1 1 / 4 1 1 / 2 1 3 / 4 2 2 1 / 4 2 1 / 2 2 3 / 4 2 7 / 8 3 3 1 / 4 3 1 / 2
2 1 / 2 18.3 17.1
3 25.8 24.0 21.8
3 1 / 2 35.6 33.5 31.0 28.2
4 1 / 4 47.9 44.7 41.3 39.3
5 1 / 4 73.5 71.6 69.7 65.5 61.0
6 89.6
Hexagon Kelly
Bore of Hexagon Kelly
Across
Flat 1 1 / 4 1 1 / 2 1 3 / 4 2 2 1 / 4 2 1 / 2 2 3 / 4 2 7 / 8 3 3 1 / 4 3 1 / 2 4
3 22.3 20.5
3 1 / 2 30.1 27.9 25.4 22.6
3 3 / 4 35.3 33.2 30.7 27.9
4 1 / 4 39.6 36.4 32.9 31.0
4 27 / 32 56.4 53.3 49.8 47.9 45.9 41.7
5 1 / 4 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 5 1 / 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 5 1 / 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 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- 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 – [(SICP-
SIDPP) ÷ 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 Dia 2 ) - Rod Dia 2 ]
Annular Capacity (bbls/ft) = (ID 2 hole -
OD 2 pipe) ÷ 1029
101
WELL CONTROL

Well Control
Capacity of DUPLEX Mud Pumps
at 100% Efficiency
Liner Dia Stroke Length (in)
(in) 12 14 16 18
4 1 / 2 0.074 0.082 – –
5 0.089 0.104 0.113 0.128
5 1 / 2 0.110 0.128 0.141 0.158
6 – 0.154 0.170 0.192
6 1 / 2 – 0.183 0.203 0.228
7 – 0.213 0.238 0.267
7 1 / 2 – 0.241 0.275 0.310
(in Bbls/stroke)
Capacity of TRIPLEX Mud Pumps
at 100% Efficiency
Liner Dia Stroke Length (in)
(in) 9 10 11 12
5 0.055 0.061 0.067 0.073
5 1 / 2 0.066 0.074 0.081 0.088
6 0.079 0.087 0.096 0.105
6 1 / 2 0.092 0.103 0.113 0.123
7 0.107 0.119 0.131 0.143
7 1 / 2 0.123 0.137 0.150 0.164
(in Bbls/stroke)
MW
SICP
SIDPP
ppg
KWM
OWM
DP
Bbls
Stk
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 Size Nominal
OD ID Weight Capacity Displacement
(in) (in) (lb/ft) (bbl/ft) (bbl/ft)
2 3 / 8 1.81 6.6 0.0032 0.0028
2 7 / 8 2.15 10.4 0.0045 0.0041
3 1 / 2 2.76 13.3 0.0074 0.0051
3 1 / 2 2.60 15.5 0.0066 0.0058
4 3.34 14.0 0.0108 0.0057
4 1 / 2 3.82 16.6 0.0142 0.0064
4 1 / 2 3.64 20.0 0.0129 0.0077
5 4.28 19.5 0.0178 0.0075
5 1 / 2 4.78 21.9 0.0222 0.0087
5 1 / 2 4.67 24.7 0.0211 0.0096
6 5 / 8 4.86 22.2 0.0229 0.0087
6 5 / 8 5.96 25.2 0.0346 0.0098
Heavy Weight Drill Pipe
Size Size
OD ID Weight Capacity Displacement
(in) (in) (lb/ft) (bbl/ft) (bbl/ft)
3 1 / 2 2.0625 25.3 0.00421 0.00921
4 2.5625 29.7 0.00645 0.01082
4 1 / 2 2.75 41.0 0.00743 0.01493
5 3.0 49.3 0.00883 0.01796
5 1 / 2 3.25 61.5 0.01030 0.02240
6 5 / 8 4.5 72.0 0.01970 0.02620
Additional capacities, displacements and weight can be
determined from the following formulas:
ID 2
CAPACITY =
= bbls/ft
1029.4
DISPLACEMENT =
OD 2 - ID 2
1029.4
= bbls/ft
WEIGHT = DISPLACEMENT bbls/ft x 2747 lbs/bbl = lbs/ft
103

Drill Collar Capacity and Displacement (bbls/ft)
ID 1 1 / 2 1 3 / 4 2 2 1 / 4 2 1 / 2 2 3 / 4 3 3 1 / 4 3 1 / 2 3 3 / 4 4 4 1/ 4
Cap 0.0022 0.0030 0.0039 0.0049 0.0061 0.0073 0.0087 0.0103 0.0119 0.0137 0.0155 0.0175
OD (in) #/ft. 36.7 34.5 32.0 29.2 - - - - - - - -
4 Disp. 0.0133 0.0125 0.0116 0.106 - - - - - - - -
4 1 / 4 #/ft. 42.4 40.0 37.5 34.7 - - - - - - - -
Disp. 0.0153 0.0145 0.0136 0.0126 - - - - - - - -
4 1 / 2 #/ft. 48.1 45.9 43.4 40.6 - - - - - - - -
Disp. 0.175 0.0167 0.0158 0.0148 - - - - - - - -
4 3 / 4 #/ft. 54.3 52.1 49.6 46.8 43.6 - - - - - - -
Disp. 0.0197 0.0189 0.0181 0.0170 0.0159 - - - - - - -
5 #/ft. 60.8 58.6 56.1 53.3 50.1 - - - - - - -
Disp. 0.0221 0.0213 0.0204 0.0194 0.0182 - - - - - - -
5 1 / 4 #/ft. 67.6 65.4 62.9 60.1 56.9 53.4 - - - - - -
Disp. 0.0246 0.0238 0.0229 0.0219 0.0207 0.0194 - - - - - -
5 1 / 2 #/ft. 74.8 72.6 70.1 67.3 64.1 60.6 56.8 - - - - -
Disp. 0.0272 0.0264 0.0255 0.0245 0.0233 0.0221 0.0207 - - - - -
5 3 / 4 #/ft 82.3 80.1 77.6 74.8 71.6 68.1 64.3 - - - - -
Disp. 0.0299 0.0291 0.0282 0.0272 0.0261 0.0248 0.0234 - - - - -
6 #/ft. 90.1 87.9 85.4 82.6 79.4 75.9 72.1 67.9 63.4 - - -
Disp. 0.0328 0.0320 0.0311 0.0301 0.0289 0.0276 0.0262 0.0247 0.0231 - - -
6 1 / 4 #/ft. 98.0 95.8 93.3 90.5 87.3 83.8 80.0 75.8 71.3 - - -
Disp. 0.0356 0.0349 0.0339 0.0329 0.0318 0.0305 0.0291 0.0276 0.0259 - - -
6 1 / 2 #/ft. 107.0 104.8 102.3 99.5 96.3 92.8 89.0 84.8 80.3 - - -
Disp. 0.0389 0.0381 0.0372 0.0362 0.0350 0.0338 0.0324 0.0308 0.0292 - - -
104

Drill Collar Capacity and Displacement (bbls/ft) (Cont.)
ID 1 1 / 2 1 3 / 4 2 2 1 / 4 2 1 / 2 2 3 / 4 3 3 1 / 4 3 1 / 2 3 3 / 4 4 4 1/ 4
Cap 0.0022 0.0030 0.0039 0.0049 0.0061 0.0073 0.0087 0.0103 0.0119 0.0137 0.0155 0.0175
6 3 / 4 #/ft. 116.0 113.8 111.3 108.5 105.3 101.8 98.0 93.8 89.3 - - -
Disp. 0.0422 0.0414 0.0405 0.0395 0.0383 0.0370 0.0356 0.0341 0.0325 - - -
7 #/ft. 125.0 122.8 120.3 117.5 114.3 110.8 107.0 102.8 98.3 93.4 88.3 -
Disp. 0.0455 0.0447 0.0438 0.0427 0.0416 0.0403 0.0389 0.0374 0.0358 0.0340 0.0321
7 1 / 4 #/ft. 134.0 131.8 129.3 126.5 123.3 119.8 116.0 111.8 107.3 102.4 97.3 -
Disp. 0.0487 0.0479 0.0470 0.0460 0.0449 0.0436 0.0422 0.0407 0.0390 0.0372 0.0354 -
7 1 / 2 #/ft. 144.0 141.8 139.3 136.5 133.3 129.8 126.0 121.8 117.3 112.4 107.3 -
Disp. 0.0524 0.0516 0.0507 0.0497 0.0485 0.0472 0.0458 0.0443 0.0427 0.0409 0.0390 -
7 3 / 4 #/ft. 154.0 151.8 149.3 146.5 143.3 139.8 136.0 131.8 127.3 122.4 117.3 -
Disp. 0.0560 0.0552 0.0543 0.0533 0.0521 0.0509 0.0495 0.0479 0.0463 0.0445 0.0427 -
8 #/ft. 165.0 162.8 160.3 157.5 154.3 150.8 147.0 142.8 138.3 133.4 123.3 122.8
Disp. 0.0600 0.0592 0.0583 0.0573 0.0561 0.0549 0.0535 0.0520 0.0503 0.0485 0.0467 0.0447
8 1 / 4 #/ft 176.0 173.8 171.3 168.5 165.3 161.8 158.0 153.8 149.3 144.4 139.3 133.8
Disp. 0.0640 0.0632 0.0623 0.0613 0.0601 0.0589 0.0575 0.0560 0.0543 0.0525 0.0507 0.0487
8 1 / 2 #/ft. 187.0 184.8 182.3 179.5 176.3 172.8 169.0 164.8 160.3 155.4 150.3 144.8
Disp. 0.0680 0.0672 0.0663 0.0653 0.0641 0.0629 0.0615 0.0600 0.0583 0.0565 0.0547 0.0527
8 3 / 4 #/ft. 199.0 196.8 194.3 191.5 188.3 184.8 181.0 176.8 172.3 167.4 162.3 156.8
Disp. 0.0724 0.0716 0.0707 0.0697 0.0685 0.0672 0.0658 0.0643 0.0697 0.0609 0.0590 0.0570
9 #/ft. 210.2 208.0 205.6 202.7 199.6 196.0 192.2 188.0 183.5 178.7 173.5 168.0
Disp. 0.0765 0.0757 0.0748 0.0738 0.0726 0.0714 0.0700 0.0685 0.0668 0.0651 0.0632 0.0612
10 #/ft. 260.9 258.8 256.3 253.4 250.3 246.8 242.9 238.8 234.3 229.4 224.2 218.7
Disp. 0.0950 0.0942 0.0933 0.0923 0.0911 0.0898 0.0884 0.0869 0.0853 0.0835 0.0816 0.0796
105

Buoyancy Factors
Mud Density
(lb/gal) (lb/cu ft) (g/cc)
Buoyancy
Factor (Kb)
8.4 62.84 1.01 0.872
8.6 64.33 1.03 0.869
8.8 65.83 1.05 0.866
9.0 67.32 1.08 0.862
9.2 68.82 1.10 0.859
9.4 70.32 1.12 0.856
9.6 71.81 1.15 0.853
9.8 73.31 1.17 0.850
10.0 74.80 1.20 0.847
10.2 76.30 1.22 0.844
10.4 77.80 1.24 0.841
10.6 79.29 1.27 0.838
10.8 80.79 1.29 0.835
11.0 82.29 1.32 0.832
11.2 83.78 1.34 0.829
11.4 85.28 1.36 0.826
11.6 86.77 1.39 0.823
11.8 88.27 1.41 0.820
12.0 89.77 1.44 0.817
12.2 91.26 1.46 0.814
12.4 92.76 1.48 0.811
12.6 94.25 1.51 0.807
12.8 95.75 1.53 0.804
13.0 97.25 1.56 0.801
13.2 98.74 1.58 0.798
13.4 100.24 1.60 0.795
13.6 101.74 1.63 0.792
13.8 103.23 1.65 0.789
106

Mud Density
(lb/gal) (lb/cu ft) (g/cc)
Buoyancy
Factor (Kb)
14.0 104.73 1.68 0.786
14.2 106.22 1.70 0.783
14.4 107.72 1.72 0.780
14.6 109.22 1.75 0.777
14.8 110.71 1.77 0.774
15.0 112.21 1.80 0.771
15.2 113.70 1.82 0.768
15.4 115.20 1.84 0.765
15.6 116.70 1.87 0.762
15.8 118.19 1.89 0.759
16.0 119.69 1.91 0.756
16.2 121.18 1.94 0.752
16.4 122.68 1.96 0.749
16.6 124.18 1.99 0.746
16.8 125.67 2.01 0.743
17.0 127.17 2.03 0.740
17.2 128.66 2.06 0.737
17.4 130.16 2.08 0.734
17.6 131.66 2.11 0.731
17.8 133.15 2.13 0.728
18.0 134.65 2.15 0.725
18.5 138.39 2.21 0.717
19.0 142.13 2.27 0.710
19.5 145.87 2.33 0.702
20.0 149.61 2.39 0.694
107

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 Mud Wt.
( Allowable
Mud Wt., ppg) - in use
ppg
( )
x(0.052)x(TVD, ft.)= psi
Test to determine H 2 S
50 ml HCl (mild hydrochloric solution)
50 ml H 2 O
1 gram NaASO 2 (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 ÷ (0.052) ÷ (TVD, ft.) + (O.M.W.) = E.C.D., ppg
Loss, psi
( )
4. Maximum Allowable Mud Weight, ppg.
Leak-Off
Test
Pressure ÷ (0.052) x (TVD, ft.)+
( Mud = ppg.
psi
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
229 Luke
Lafayette, Louisiana 70506
337.232.3098
Fax: 337.261.1066
ABERDEEN
Grant Prideco
Suite C, 1St Swithin Row
Aberdeen AB 10 6DL
011.44.1224.597300
Fax: 011.44.1224.589420
CANADA
Grant Prideco
Suite1440, 510-5th Street SW
Calgary, Alberta, Canada T2P 3S2
403.571.2567
Fax: 403.705.1754
CENTRAL/SOUTH AMERICA
Grant Prideco
Av. Principal, Urb. Chaguaramal, Edf.
Las Rocas Suites 10-a
Valencia, Venezuela
011.58.241.824.7027
Fax: 011.58.241.824.9190
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
Grant Prideco
113114 Moscow, Russia
Shluzovaya Nab. 6, Bldg. 1-2
011.70.95.960.2404
Fax: 011.70.95.960.2405
S.E. ASIA/OCEANIA
Citra Grant Prideco Marketing Ltd
No. 11 Tuas Avenue 7
Singapore 639266
011.65.6861.4266
Fax: 011.65.6861.0117
SOUTHERN EUROPE & AFRICA
Grant Prideco
102 Franklin Roosevelt Blvd.
92 500 Rueil Malmaison
Paris, France
011.33.147.080830
Fax: 01133.147.080849
UAE/MIDDLE EAST
Grant Prideco
Dubai Airport Free Zone
East Wing2, 4th Floor, Office 2E-404
Dubai
United Arab Emirates
011.971.4.299.6446
Fax: 011.971.4.299.6424
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