rotary shoulder handbook

Transcription

ROTARY SHOULDER HANDBOOK
Revised GP-7033 Handbook_Cover.indd 1
11/18/2010 5:33:17 PM
Contents
Section I ................................... Drill Pipe
Section II .................................. Double-Shouldered Connections
SECTION III................................ Heavy Weight Drill Pipe
SECTION IV ............................... Drill Collars
SECTION V ................................ Subs and Kellys
SECTION VI ............................... Well Control
© 2010 National Oilwell Varco
This handbook is a summary of the technical data from API Spec. 5 DP Latest Edition,
API 7-1 and 7-2 Latest Edition, API RP 7G Latest Edition, etc., for the purpose of easier
application in the field.
NOV® 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, NOV 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. No expressed or implied warranty is
intended.
11/18/2010 5:35:05 PM
DRILL PIPE
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. If a torque range is
given, maximum recommended makeup torque should be applied
when possible.
2. Make up connections slowly, preferably using chain tongs. High
speed kelly spinners or the spinning chain used on initial make-up
can cause galling of the threads.
3. Tong them up to the predetermined torque using a recently
calibrated torque gauge to measure the required line-pull.
Note: Monitor breakout torque. It should be less than or no greater
than make-up torque. If it is greater, the connection should be
cleaned, inspected and repaired, before it is made up again.
4. Breakout, visually inspect, redope and make up two more times
before running in hole. Always use backup tongs to make and
break connections.
5. Stagger breaks on each trip so that each connection can be checked,
redoped and made up every second or third trip, depending on the
length of drill pipe and size of rig.
A new string of drill pipe deserves good surface handling equipment and
tools. Check slips and master bushings before damage occurs to the tube.
(See the IADC Drilling Manual for correct measurements).
Do not stop the downward movement of the drill stem with the slips. This
can cause crushing or necking down of the drill pipe tube. The drill pipe can
also be damaged by allowing the slips to ride the pipe on trips out of the
hole.
Good rig practices will help eliminate time consuming trips in the future,
looking for washouts or fishing for drill pipe lost in the hole. For more
information refer to the IADC Drilling Manual.
1
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Torque Chart-Drill Pipe Tool Joint
New Tool Joints
Drill Pipe
Size
(in)
2 3/8
2 7/8
3 1/2
4
Connection
Box
OD1
(in)
Pin
ID
(in)
Make-up
Torque2,3
(ft-lb)
NC26 (IF)
OHLW
OHSW
SLH-90
WO
PAC
2 7/8” SH (NC26)
OHLW
OHSW
SLH-90
SLH-90
PAC
WO
X.H.
NC31 (IF)
NC31 (IF)
NC31 (IF)
3 1/2 SH (NC31)
SLH-90
SLH-90
OHLW
OHSW
NC38 (WO)
NC38 (IF)
NC38 (IF)
NC38 (IF)
NC38 (IF)
NC40 (4” FH)
NC40 (4” FH)
NC40 (4” FH)
SH (3 1/2”XH)
OHLW
OHSW
NC40 (4” FH)
NC40 (4” FH)
NC40 (4” FH)
NC40 (4” FH)
NC46 (WO)
NC46 (IF)
NC46 (IF)
NC46 (IF)
NC46 (IF)
NC46 (IF)
NC46 (IF)
NC46 (IF)
3 3/8
3 1/8
3 1/4
3 1/4
3 3/8
2 7/8
3 3/8
3 3/4
3 7/8
3 7/8
3 7/8
3 1/8
4 1/8
4 1/4
4 1/8
4 1/8
4 3/8
4 1/8
4 5/8
4 5/8
4 3/4
4 3/4
4 3/4
4 3/4
5
5
5
5 1/4
5 3/8
5 1/2
4 5/8
5 1/4
5 1/2
5 1/4
5 1/4
5 1/2
5 1/2
5 3/4
6
6
6
6
6
6
6
1 3/4
2
1 3/4
2
2
1 3/8
1 3/4
2 7/16
2 5/32
2 7/16
2 5/32
1 1/2
2 7/16
1 7/8
2 1/8
2
1 5/8
2 1/8
3
2 11/16
3
2 11/16
3
2 11/16
2 9/16
2 7/16
2 1/8
2 9/16
2 7/16
2 1/4
2 9/16
3 15/32
3 1/4
2 13/16
2 11/16
2 7/16
2 7/16
3 7/16
3 1/4
3
3
3 1/4
3
2 5/8
2 7/8
3,900
2,600
3,700
2,700
2,400
2,600
3,900
3,100
4,800
4,000
5,900
3,200
3,900
7,000
6,400
7,100
9,000
6,400
6,500
9,500
6,500
9,300
6,800
9,700
10,700
11,700
14,000
14,600
15,600
17,100
8,100
11,900
14,700
12,400
13,500
15,600
15,600
15,200
17,600
20,500
20,500
17,600
20,500
24,400
21,900
Notes:
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 RP7G Latest Edition. The make-up
values are lower due to the combined torsional and tensile loads found in service conditions.
2
11/18/2010 5:36:06 PM
Used Tool Joints
Premium
Class 2
Box
OD1
(in)
Make-Up
Torque2,3
(ft-lb)
Box
OD1
(in)
Make-Up
Torque2,3
(ft-lb)
3 1/4
3 1/16
3
2 31/32
3 1/16
2 25/32
3 3/8
3 1/2
3 19/32
3 17/32
3 19/32
3 1/8
3 5/8
3 23/32
3 11/16
3 29/32
4 1/16
4
4 3/16
4 3/8
4 9/32
4 3/8
4 3/8
4 3/8
4 19/32
4 21/32
4 23/32
4 15/32
5
5 3/32
4 7/16
4 31/32
5 1/32
4 13/16
4 15/16
5
5
5 7/32
5 5/32
5 7/16
5 15/32
5 9/32
5 9/16
5 5/8
5 5/8
3,000
2,300
1,800
2,000
2,000
2,500
3,900
3,100
4,300
3,800
4,500
3,500
3,200
4,400
3,200
5,700
7,700
6,400
5,500
8,800
5,500
7,000
5,300
5,300
8,800
9,900
10,900
11,400
12,600
14,400
8,800
7,500
8,800
9,000
11,400
12,600
12,600
7,900
10,000
12,800
13,600
9,200
15,800
17,300
17,300
3 3/16
3 1/32
2 31/32
3 31/32
3
2 23/32
3 5/16
3 7/16
3 17/32
3 17/32
3 17/32
3 1/16
3 9/16
3 21/32
3 21/32
3 13/16
3 31/32
3 29/32
4 1/8
4 9/32
4 7/32
4 5/16
4 11/32
4 11/32
4 1/2
4 9/16
4 5/8
4 13/32
4 7/8
4 15/16
4 11/32
4 29/32
4 31/32
4 23/32
4 13/16
4 7/8
4 7/8
5 5/32
5 7/32
5 5/16
5 3/8
5 3/16
5 7/16
5 1/2
5 1/2
2,500
2,100
1,600
2,000
1,500
2,100
3,600
2,700
3,600
3,800
3,800
3,500
2,500
3,700
2,800
4,600
6,500
5,700
4,500
7,100
4,600
6,000
4,800
4,800
7,300
8,300
9,300
9,000
10,200
11,400
7,400
6,200
7,500
7,300
9,000
10,200
10,200
6,500
7,900
10,000
11,400
7,200
12,800
14,300
14,300
Notes (cont):
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
TAB 1 RSHandbook_Drill Pipe.indd 3
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Torque Chart-Drill Pipe Tool Joint (cont.)
New Tool Joints
Drill Pipe
Size
(in)
4 1/2
5
5 1/2
6 5/8
Connection
Box
OD1
(in)
Pin
ID
(in)
Make-up
Torque2,3
(ft-lb)
OHSW
FH
FH
FH
NC46 (XH)
NC46 (XH)
NC46 (XH)
NC46 (XH)
NC50 (IF)
NC50 (IF)
NC50 (IF)
NC50 (IF)
NC50 (IF)
NC50 (XH)
NC50 (XH)
NC50 (XH)
NC50 (XH)
NC50 (XH)
5 1/2” FH
5 1/2” FH
5 1/2” FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
FH
5 7/8
6
6
6
6 1/4
6 1/4
6 1/4
6 1/4
6 3/8
6 3/8
6 3/8
6 3/8
6 3/8
6 3/8
6 3/8
6 1/2
6 1/2
6 5/8
7
7 1/4
7 1/4
7
7
7
7 1/4
7 1/4
7 1/4
7 1/2
7 1/2
8
8
8
8 1/4
8 1/4
8 1/4
8 1/2
8 1/2
3 3/4
3
2 3/4
2 1/2
3 1/4
3
2 3/4
2 1/2
3 3/4
3 3/4
3 5/8
3 1/2
2 7/8
33/4
3 1/2
3 1/4
3
2 3/4
3 1/2
3 1/2
3 1/4
4
4
3 3/4
3 1/2
3 1/2
3 1/2
3
3
5
5
5
4 3/4
4 3/4
4 3/4
4 1/4
4 1/4
14,600
17,600
20,100
22,300
17,600
20,500
23,200
25,600
19,800
19,800
21,600
23,400
30,300
19,800
23,400
26,800
30,000
32,900
37,400
37,400
41,200
29,200
29,200
33,400
37,400
37,400
37,400
44,600
44,600
38,400
38,400
38,400
44,600
44,600
44,600
56,100
56,100
Notes:
1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on
Slim Hole (SH) tool joints due to special service requirements.
2. Make-up torque values may be lower than those published in API RP7G Latest Edition. The make-up
values are lower due to the combined torsional and tensile loads found in service conditions.
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.
4
Used Tool Joints
Premium
Class 2
Box
OD1
(in)
Make-Up
Torque2,3
(ft-lb)
Box
OD1
(in)
Make-up
Torque2,3
(ft-lb)
5 15/32
5 3/8
5 9/16
5 5/8
5 13/32
5 19/32
5 25/32
5 23/32
5 29/32
5 23/32
5 13/16
5 15/16
6 7/32
5 7/8
6 1/32
6 3/32
6 3/16
6 5/16
6 21/32
6 23/32
6 15/16
6 17/32
6 9/16
6 5/8
6 23/32
6 25/32
6 25/32
7 1/32
7 1/32
7 7/16
7 1/2
7 5/8
7 11/16
7 11/16
7 3/4
7 29/32
8
12,300
12,100
16,400
17,800
12,100
16,500
21,200
19,600
16,600
11,600
14,100
17,500
25,500
15,800
20,200
21,900
24,700
28,400
25,500
27,700
35,500
21,300
22,300
24,500
27,650
29,900
29,900
39,000
39,000
26,800
29,500
35,100
38,000
38,000
40,900
48,200
52,700
5 3/8
5 9/32
5 7/16
5 15/32
5 5/16
5 15/32
5 5/8
5 9/16
5 25/32
5 21/32
5 23/32
5 27/32
6 1/16
5 25/32
5 29/32
5 31/32
6 1/32
6 3/16
6 1/2
6 9/16
6 3/4
6 7/16
6 15/32
6 1/2
6 19/32
6 5/8
6 11/16
6 27/32
6 7/8
7 3/8
7 13/32
7 1/2
7 9/16
7 19/32
7 21/32
7 25/32
7 27/32
10,000
10,100
13,500
14,200
9,900
13,500
17,300
15,800
13,200
10,000
11,600
14,900
21,000
13,300
16,700
18,400
22,000
24,600
20,200
22,300
28,800
18,200
19,200
20,300
23,350
24,500
26,560
32,100
33,200
24,100
25,500
29,500
32,300
33,700
36,500
42,300
45,200
5
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6 5/8
5 7/8
5 1/2
5
4 1/2
4
3 1/2
2 7/8
2 3/8
Size
OD
(in)
0.262
0.330
0.380
0.271
0.337
0.430
0.362
0.500
0.361
0.415
0.361
0.415
0.330
0.362
13.75
16.60
20.00
19.50
25.60
21.90
24.70
23.40
26.30
25.20
27.70
0.190
0.280
0.217
0.362
0.254
0.368
0.449
4.85
6.65
6.85
10.40
9.50
13.30
15.50
11.85
14.00
15.70
Wall
Thickness
(in)
Nominal
Weight
(lb/ft)
3.958
3.826
3.640
4.276
4.000
4.778
4.670
5.153
5.045
5.965
5.901
3.476
3.340
3.240
1.995
1.815
2.441
2.151
2.992
2.764
2.602
ID
(in)
3.6004
4.4074
5.4981
5.2746
7.0686
5.8282
6.6296
6.2535
7.1185
6.5262
7.1226
3.0767
3.8048
4.3216
1.3042
1.8429
1.8120
2.8579
2.5902
3.6209
4.3037
7.184
8.542
10.232
11.416
14.490
14.062
15.688
16.251
18.165
19.572
21.156
5.400
6.458
7.156
1.320
1.734
2.242
3.204
3.922
5.144
5.846
25,860
30,750
36,840
41,090
52,160
50,620
56,470
58,600
65,500
70,550
76,300
19,440
23,250
25,760
E75
4,760
6,240
8,070
11,530
14,120
18,520
21,050
32,760
38,950
46,660
52,050
66,070
64,120
71,530
74,200
83,000
89,360
96,600
24,620
29,450
32,630
X95
6,020
7,900
10,220
14,610
17,890
23,460
26,660
36,210
43,050
51,570
57,530
73,030
70,870
79,060
82,000
91,700
98,770
106,800
27,220
32,550
36,070
G105
6,060
8,740
11,300
16,150
19,770
25,930
29,470
Torsional Yield Strength (ft-lb)
46,550
55,350
66,300
73,970
93,900
91,120
101,650
105,500
117,900
127,044
137,300
34,990
41,840
46,380
S135
–
–
–
20,760
25,420
33,330
37,890
New Drill Pipe Dimensional, Torsional and Tensile Data
Cross
Polar
Sectional Sectional
Area
Modulus
of Pipe
Z
(sq in)
(cu in)
270,030
330,560
412,360
395,600
530,140
437,120
497,220
469,000
533,900
489,460
534,200
230,750
285,360
324,150
E75
97,820
138,220
135,900
214,340
194,260
271,570
322,780
342,040
418,700
522,320
501,090
671,520
553,680
629,810
594,100
676,300
619,990
676,700
292,290
361,460
410,590
X95
123,900
175,080
172,140
271,500
246,070
343,990
408,850
378,050
462,780
577,300
553,830
742,200
611,960
696,110
656,600
747,400
685,250
747,900
323,050
399,500
453,810
G105
136,940
193,500
190,260
300,080
271,970
380,190
451,890
Tensile Yield Strength (lb)
486,060
595,000
742,240
712,070
954,260
786,810
895,000
844,200
961,000
881,044
961,600
415,360
513,650
583,420
S135
176,070
248,790
244,620
385,820
349,680
488,820
581,000
Performance Properties of Seamless Drill Pipe
6
11/18/2010 5:36:42 PM
E75
11,040
15,600
10,470
16,510
10,040
14,110
16,770
8,410
11,350
12,900
7,200
10,390
12,960
10,000
13,500
8,440
10,460
7,450
9,560
4,810
5,890
Nominal
Weight
(lb)
4.85
6.65
6.85
10.40
9.50
13.30
15.50
11.85
14.00
15.70
13.75
16.60
20.00
19.50
25.60
21.90
24.70
23.40
26.30
25.20
27.70
Size
OD
(in)
2 3/8
2 7/8
3 1/2
4
4 1/2
7
5
5 1/2
5 7/8
6 5/8
5,310
6,750
8,770
11,500
10,000
12,920
12,010
17,100
8,400
12,750
16,420
9,960
14,380
16,340
12,060
17,880
21,250
12,930
20,910
X95
13,980
19,760
5,490
7,100
9,360
12,410
10,740
14,000
12,990
18,900
8,950
13,820
18,150
10,700
15,900
18,050
13,050
19,760
23,480
14,010
23,110
G105
15,460
21,840
Collapse Pressure, (psi)
6,040
7,810
10,820
14,890
12,710
17,050
15,700
24,300
10,310
16,800
23,330
12,650
20,170
23,210
15,780
25,400
30,190
17,060
29,720
S135
19,070
28,080
6,540
7,170
8,060
9,270
8,610
9,900
9,500
13,120
7,900
9,830
12,540
8,600
10,830
12,470
9,520
13,800
16,840
9,910
16,530
E75
10,500
15,470
Material Grade
8,280
9,080
10,220
11,740
10,910
12,540
12,040
16,620
10,010
12,450
15,890
10,890
13,720
15,790
12,070
17,480
21,330
12,550
20,930
X95
13,300
19,600
9,150
10,040
11,290
12,980
12,060
13,860
13,300
18,380
11,070
13,760
17,560
12,040
15,160
17,460
13,340
19,320
23,570
13,870
23,140
G105
14,700
21,660
Internal Pressure, (psi)
11,770
12,910
14,520
16,690
15,510
17,830
17,110
23,620
14,230
17,690
22,580
15,480
19,490
22,440
17,150
24,840
30,310
17,830
29,750
S135
18,900
27,850
New Drill Pipe Collapse and Internal
Pressure Data
Tool Joint Bevel Diameters
Type
Internal
Flush
&
Numbered
Connections
Full Hole
&
Numbered
Connections
Xtra Hole &
Numbered
Connections
Size (in)
OD (in)
Bev. Dia. (in)
2 3/8 & NC26
3 3/8
3 17/64
3 61/64
2 7/8 & NC31
4 1/8
3 1/2 & NC38
4 3/4
4 37/64
3 1/2 & NC38
5
4 37/64
NC40
5 1/2
5 1/64
4 & NC46
6
5 23/32
4 & NC46
6 1/4
5 23/32
4 1/2 & NC50
6 1/8
6 1/16
4 1/2 & NC50
6 1/4
6 1/16
4 1/2 & NC50
6 3/8
6 1/16
4 1/2 & NC50
6 1/2
6 1/16
4 1/2 & NC50
6 5/8
6 1/16
NC56
7
6 47/64
3 1/2
4 5/8
4 31/64
4 & NC40
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
3 1/2
4 3/4
4 17/32
4 1/2 & NC46
6
5 23/32
5 & NC50
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
3 23/32
H-90
Slimline
H-90
Slimhole
&
Numbered
Connections
2 7/8
3 7/8
3 1/2
4 5/8
4 7/16
2 3/8
2 7/8
2 25/32
2 7/8 & NC26
3 3/8
3 17/64
3 1/2 & NC31
4 1/8
3 61/64
4
4 1/2
4 11/32
4
4 5/8
4 11/32
4 1/2 & NC38
5
4 37/64
8
11/18/2010 5:36:43 PM
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
11/18/2010 5:36:43 PM
Conversion of Customary Units to SI/Metric Units
Conversion
Customary to
SI/Metric
Multiply by
25.4
645.16
0.028317
4.546092
3.785412
0.017453
60
0.453592
(°F-32)
1.8
Customary
Units
(Abbreviation)
SI/Metric
Units
(Abbreviation)
Plane angle
Time
Mass
in
sq in
cu ft
U.K. gal
U.S. gal
deg (0)
min
lbm
mm
mm2
m3
L
L
rad
S
kg
Temperature (traditional)
°F
°C
Pressure
lbf/in2(psi)
N/m2
at (kp/cm2)
bar
bar
Pa
bar
Pa
0.068947
1.
1.0197
105
lbm/U.S. gal
lbm/U.K. gal
lbm/ft
lbm/ft3
lbm/hr
bbl/D
ft3/D
U.K. gal/min
U.S. gal/min
kg/m3
kg/m3
kg/m3
kg/m3
kg/h
m3/h
m3/h
L/min
L/min
119.8264
99.77633
16.01846
16.01846
0.453592
0.006624
0.001179
4.546092
3.785412
Flow rate (volume basis)
U.K. gal/min
U.S. gal/min
ft3/min
L/min
L/min
m3/min
4.546092
3.785412
0.028314
Energy work
Btu
ft-lbf
lbf-ft
K N-m
kWh
kJ
kJ
kJ
0.000293
0.001356
0.001356
1.
hydraulic horse
power-hhp
hp (electric)
Btu/hr
kW
0.746043
Power
kW
W
0.746
0.293071
mile/U.S. gal
mile/U.K. gal
ft/min
in/s
rev/s
rev/min
lb/ft
lbf
kg-m/sec 2
lbf-ft
cu in
kgf/mm2
lbf/in2 (psi)
km/L
km/L
m/s
mm/s
rev/s
rev/s
kg/m
N
N
Nm
mm3
N/mm2
N/mm2
0.425144
0.354066
0.005080
25.4
1.0
0.016666
1.488164
4.448222
1.
1.355818
2831685
9.806650
0.006895
Basic
Unit
Length
Area
Volume, capacity
Density (liquids)
Density (solids)
Throughput (mass basis)
Throughput (volume basis)
Fuel consumption
Velocity (linear) speed
Rotational frequency
Weight/length
Force
Bending moment torque
Section modulus
Stress
10
11/18/2010 5:36:43 PM
Drill Pipe with Double-Shouldered Connections
Box
Pipe
Hardbanding
External Upset
Tool Joint
Pin
Weld
Internal Upset
Internal Coating
DOUBLESHOULDERED
CONNECTIONS
Elevator Shoulder
Pin Base
Primary Shoulder
Pin base extends in
spring-like manner
when joint is bucked
up to recommended
make-up torque.
Provides seal and
preload just as on
conventional tool
joint.
Secondary
Shoulder
Box Counterbore
Section
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 compresses
in spring-like
manner when joint
is bucked up to
recommended
make-up torque.
Pin Nose
11
11/18/2010 5:36:06 PM
Types of Grant Prideco Double-Shouldered
Connections
Double-shouldered connections offered by NOV Grant Prideco include:
• HI TORQUE® (HT™) – First generation double-shouldered connection
providing approximately 40% more torque capacity than API
connections of equivalent dimensions. Not interchangeable with
API connections.
• eXtreme® Torque (XT®) – Second generation double-shouldered
connection providing approximately 65% more torque capacity than
API connections of equivalent dimensions. Not interchangeable with
API connections. Primary differences exist between HT and XT connections are XT has a shallow taper and a fatigue-resistant thread
form.
– eXtreme® Torque with Metal-to-Metal Seal (XT-M™) –
Industry's first gas-tight pressure rated rotary-shouldered
connection with a metal-to-metal seal. The radial seal provides
a pressure rating of 15,000 psi internal, and 10,000 psi external.
This provides torque capacity similar to that of XT connections.
Not interchangeable with API connections.
The figure below illustrates the taper difference between HT® and XT®
connections.
HT
XT
• Grant Prideco Double Shoulder® (GPDS®) – Double-shouldered
connection that is interchangeable with API connections and
provides approximately 40% more torque capacity than API
connections of equivalent dimensions.
12
• TurboTorque® – Third generation double shoulder connection
providing approximately 80% more torque capacity than API
connections of equivalent dimensions, and 10-15% over XT®.
Not interchangeable with API connections. Primary benefits
for TurboTorque connections include: it saves time, cuts costs;
increases torque capacity; optimizes hydraulics; improves
clearance and fishability; reduces risk of failure; and extends life
of the connection itself.
– TurboTorque-M™ with Metal-To-Metal Seal – Gas-tight
pressure-rated rotary shoulder connection. The radial seal
provides a pressure rating of 20,000 psi internal, and
10,000 psi external. Torque capacity is similar to that of
TurboTorque connections. Not interchangeable with API
connections.
XT®57
≈ 13 revolutions
Starting Thread
Starting Thread 1
TurboTorque®
585
≈ 4 revolutions
Starting Thread 2
TurboTorque connections are the first in the industry to provide
a Turbo-MUT™. Also known as "torque-on-demand", Turbo-MUT
provides an additional 8% of torque capacity for those unusual
drilling situations when additional torque is required. Most of the
testing and design validation for the TurboTorque family were
conducted on connections made up to the Turbo-MUT value.
13
TAB 2 RSHandbook_DSC.indd Sec1:13
11/18/2010 5:37:04 PM
TurboTorque® Tool Joint Make-up Torque Chart
Type
Connection
Box
OD
(in)
Pin
ID
(in)
Minimum
MUT
(ft-lb)
Recommended
Turbo-MUT™
MUT
(ft-lb)1
(ft-lb)
TurboTorque 380
4 3/4
4 13/16
2 11/16
2 1/2
16,800
19,900
20,200
23,900
21,900
25,900
TurboTorque 390
4 7/8
2 11/16
19,600
23,500
25,500
TurboTorque 420
5 1/4
2 15/16
23,700
28,400
30,800
TurboTorque 435
5 3/8
3 1/8
24,700
29,600
32,100
TurboTorque 485
6
6 1/8
3 9/16
3 1/4
31,500
39,700
37,800
47,600
40,900
51,600
TurboTorque 500
6 1/4
3 1/2
38,900
46,600
50,500
TurboTorque 525
6 1/2
6 5/8
3 7/8
3 9/16
38,200
48,000
45,800
57,600
49,600
62,400
TurboTorque 550
6 5/8
4 1/4
39,100
46,900
50,900
TurboTorque 585
7
7 1/8
4 1/2
4 5/16
47,800
55,500
57,300
66,600
62,100
72,200
TurboTorque 690
8 1/4
5 1/2
63,100
75,800
82,100
Note:
1. Applies to drill pipe and heavy weight drill pipe tool joints. See page 13.
14
TurboTorque-M™ Tool Joint Make-up
Torque Chart
Type
Connection
Box
OD
(in)
Pin
ID
(in)
Minimum
MUT
(ft-lb)
Recommended
Turbo-MUT™
MUT
(ft-lb)1
(ft-lb)
TurboTorque-M 380
4 3/4
4 13/16
2 11/16
2 1/2
14,800
17,900
17,700
21,400
19,200
23,200
TurboTorque-M 390
4 7/8
2 11/16
17,400
20,900
22,700
TurboTorque-M 420
5 1/4
2 15/16
21,200
25,500
27,600
TurboTorque-M 435
5 3/8
3 1/8
22,000
26,400
28,600
TurboTorque-M 485
6
6 1/8
3 9/16
3 1/4
28,200
36,500
33,900
43,800
36,700
47,400
TurboTorque-M 500
6 1/4
3 1/2
35,400
42,500
46,000
TurboTorque-M 525
6 1/2
6 5/8
3 7/8
3 9/16
34,400
44,200
41,200
53,100
44,700
57,500
TurboTorque-M 550
6 5/8
4 1/4
43,900
41,800
45,300
TurboTorque-M 585
7
7 1/8
4 1/2
4 5/16
43,000
50,800
51,600
60,900
55,900
66,000
TurboTorque-M 690
8 1/4
5 1/2
58,800
70,600
76,500
TurboTorque-M 710
8 1/2
5 5/8
65,400
78,500
85,000
Note:
1. Applies to drill pipe and heavy weight drill pipe tool joints. See page 13.
15
11/18/2010 5:37:08 PM
XT® Tool Joint Make-up Torque Chart
Type
Connection
Box OD
(in)
Pin ID
(in)
XT®
Recommended MUT
(ft-lb)
XT24
3 1/8
3 1/2
3 1/2
3 1/2
3 3/4
4 1/8
4 1/8
4
4
1 1/2
1 3/4
1 1/2
1 1/4
2
2
1 7/8
2
2 1/8
5,700
6,900
8,900
9,900
9,000
12,700
14,000
12,200
11,200
XT38
4 7/8
4 7/8
4 3/4
4 3/4
4 3/4
2 9/16
2 7/16
2 11/16
2 9/16
2 7/16
18,900
20,900
16,600
18,800
20,500
XT39
4 7/8
4 7/8
4 7/8
5
5
5
5
4 7/8
2 9/16
2 3/4
2 13/16
2 7/8
2 13/16
2 11/16
2 9/16
2 11/16
22,200
20,700
19,800
18,600
19,800
22,200
24,500
21,200
XT40
5 1/4
5 1/4
3
2 13/16
22,400
26,400
5 3/4
5 3/8
6 1/4
6 5/8
6 5/8
6 1/2
6 3/8
6 3/8
6 3/4
6 5/8
7 3/8
7
2 3/4
3
3 1/4
3 3/4
3 1/2
3 3/4
3 3/4
3 1/2
4
4
3 5/8
4
34,000
28,300
42,100
46,400
54,400
46,200
45,100
48,700
52,000
49,900
72,200
58,100
XT57
7 1/4
7 1/4
7 1/4
7 1/4
7 1/8
7
7
7
7
3 3/4
3 1/2
3 1/4
3 3/16
3 1/4
4 1/4
4
3 3/4
3 1/2
76,300
81,500
84,900
85,700
79,900
56,600
63,700
67,900
71,600
XT65
XT69
8
8 1/2
5
5 1/4
81,200
100,300
XT26
XT29
XT31
XT43
XT46
XT50
XT54
XT55
Note: Applies to drill pipe and heavy weight drill pipe tool joints.
16
11/18/2010 5:37:08 PM
XT-M™ Tool Joint Make-up Torque Chart
Type
Connection
Box OD
(in)
Pin ID
(in)
XT-M™
Recommended MUT
(ft-lb)
XT-M26
3 3/8
4
4
3 7/8
4 1/4
4 3/4
4 3/4
1 3/4
2
2 1/8
2 1/8
2 9/16
2 9/16
2 11/16
5,000
10,800
9,700
8,500
9,700
16,700
14,500
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
2 7/16
2 9/16
2 13/16
2 11/16
2 11/16
3
3 1/4
3
23,300
22,300
17,700
18,900
26,200
23,500
19,500
45,100
3 1/2
3 3/4
3 1/2
3 5/8
6 3/8
7 1/4
7
7
7
8
8 1/2
4
4 1/4
4
4 1/8
4 1/4
5
5 1/4
50,300
42,100
40,700
38,900
41,500
51,900
58,700
56,500
51,600
74,600
92,900
XT-M31
XT-M34
XT-M38
XT-M39
XT-M40
XT-M43
XT-M46
XT-M50
XT-M54
XT-M57
XT-M65
XT-M69
17
11/18/2010 5:37:08 PM
GPDS® Tool Joint Make-up Torque Chart
Box OD
(in)
Pin ID
(in)
GPDS®
Recommended MUT
(ft-lb)
3 3/8
3 1/2
3 1/2
4 1/8
4 1/8
1 3/4
1 11/16
1 5/8
2
1 7/8
5,200
5,800
6,300
10,300
11,600
GPDS38
5
5
5
4 7/8
4 7/8
2 7/16
2 9/16
2 1/4
2 9/16
2 7/16
17,500
15,500
20,300
15,400
17,400
GPDS40
5 1/2
5 3/8
5 1/4
5 1/4
5 1/4
5 1/4
2 7/16
2 1/2
2 11/16
2 5/8
2 9/16
2 1/2
24,200
23,000
19,600
20,800
21,900
22,900
GPDS46
6
6
6
6
6
6
3 1/4
3 3/16
3 1/8
3
2 15/16
2 3/4
25,700
27,300
28,800
31,800
33,200
37,200
GPDS50
6 5/8
6 5/8
6 5/8
6 1/2
6 1/2
6 1/2
2 3/4
3
3 1/4
3 1/4
3 1/2
3 3/4
54,400
49,700
43,300
43,100
36,100
28,500
GPDS55
7 1/4
7 1/8
7
7
7
3 3/4
3 3/4
3 1/2
3 3/4
4
53,800
53,600
53,900
50,300
44,500
GPDS65
8 1/4
8 1/2
8
4 3/4
4 1/4
4 7/8
70,400
94,800
63,600
Type
Connection
GPDS26
GPDS31
18
11/18/2010 5:37:08 PM
HT® Tool Joint Make-up Torque Chart
Box OD
(in)
Pin ID
(in)
HT®
Recommended MUT
(ft-lb)
3 1/8
3 1/8
3 1/8
3 1/8
1.975
1 3/4
1 1/2
1 3/8
4,600
5,600
5,100
5,900
HT26
3 5/8
3 5/8
3 5/8
3 1/2
3 3/8
1 1/2
1 3/8
1 1/4
1 1/2
1 3/4
7,900
8,700
9,200
7,300
5,200
HT31
4 1/4
4 1/8
4 1/8
4 1/8
1 3/4
2 1/8
2
1 7/8
14,000
10,000
11,300
11,900
HT38
5
5
4 3/4
4 3/4
4 3/4
4 7/8
2 9/16
2 7/16
2 11/16
2 9/16
2 7/16
2 9/16
17,700
19,800
15,200
16,100
17,000
17,700
HT40
5 1/8
5 1/8
5 1/2
5 1/4
5 1/4
2 9/16
2 11/16
2 9/16
2 13/16
2 11/16
21,100
20,100
24,000
19,200
21,500
HT46
6 1/4
6 1/4
3 1/4
3
28,500
34,600
HT50
6 5/8
6 5/8
6 5/8
6 5/8
6 3/8
6 1/4
3 3/4
3 1/2
3 1/4
3
3 1/2
3 3/4
32,000
39,700
46,800
53,300
39,400
31,600
HT55
7 1/2
7 3/8
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 1/8
7
7
3 3/16
3 3/8
4
3 3/4
3 1/2
3 1/4
3
4
3 7/8
3 1/2
3 1/4
4
3 3/4
73,800
68,000
46,700
55,600
63,900
69,000
72,000
46,500
51,100
61,000
64,200
46,300
52,600
HT65
8 1/2
8 1/2
8 1/4
8
5
4 1/4
4 13/16
5
60,500
97,800
70,100
59,800
Type
Connection
2 3/8 HTSLH90
2 7/8 HTPAC
19
11/18/2010 5:37:09 PM
The following sections provide general guidelines for running and handling doubleshouldered connections. Connection-specific procedures are available directly from
NOV Grant Prideco and can be downloaded from: www.nov.com/grantprideco
Picking Up Pipe with Double-Shouldered
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
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 a problem
is 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.
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 up the joints 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 up the joints again to the same make-up torque and
break them out. Separate the pin and box and reapply thread
compound.
Step 3: Make up the joints again to the same make-up 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.
20
11/18/2010 5:37:09 PM
Special Considerations When Running XT®,
TurboTorque®, XT-M™ and TurboTorque-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 stabbing and make-up.
• Ensure the bore through the top drive bell stabbing guide (top drive
flipper) is no more than ½” larger in diameter than the box tool joint
diameter.
• Because of the shallow taper, connections do not stab as deep into
the box as API connections. Alignment of the pin to the box when
stabbing and spinning up is more critical for shallow taper connections.
• 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 protruding metal should be
removed with a soft grinding wheel or a file.
• A stabbing guide is required when running XT, XT-M and
TurboTorque-M™ connections and alignment should be verified
before spinning up. A stabbing guide is recommended for HT®,
GPDS®, and TurboTorque connections.
21
11/18/2010 5:37:09 PM
Application of Thread Compound to
Double-Shouldered Connections
• All contacting surfaces – the threads, the primary shoulders, secondary shoulders and 15° metal seal (XT-M™, TurboTorque-M™) – must
be coated with a good quality rotary-shouldered connection thread
compound. Copper-based thread compounds are recommended
because of the anti-galling resistance, the repeatability of frictional
characteristics and the generally higher friction coefficient (yielding
less stress in the connection for equivalent MUTs). Standard API
thread compounds are sufficient.
• 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° metal seal
(XT-M, TurboTorque-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 secondary
shoulder and 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 and TurboTorque-M connections, localized corrosion
or pitting may occur on the 15° metal 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 and TurboTorque-M connections.
Primary
Shoulder
Threads
Secondary
Shoulder
15° Metal Seal
22
11/18/2010 5:37:09 PM
Tonging and Proper Gripping of the Box During
Makeup
• Tongs should be placed per chart below:
A.
Connection
B.
Minimum Grip
Distance from
Makeup Shoulder
(in)
C.
Minimum Tong
Pin
(in)
Box
(in)
API
75% OD, 4 min
box depth + 1
GPDS™
75% OD, 4 min
box depth + 1
8
XT-M™, GT-M™, XT® long
counterbore
2
6
CT-M™57
1
6
7
CT-M™43
1
6
7
TT® and TT-M™ mid sizes
2
6
8
XT® short counterbore
1.5
6
7.5
TT® and TT-M™ small sizes
1
6
7
TT® and TT-M™ large sizes
1.5
6
7.5
• Back-up tongs should always be used.
See Chart,
column B.
Recommended
Tonging Area
23
11/18/2010 5:37:09 PM
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 RP7G Latest Editon about height of tool joint above slips to
prevent bending pipe during tonging.
P
P
H max
24
11/18/2010 5:37:09 PM
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 (see figure below). This
can cause high contact stresses and may 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. Alignment for all connections should be verified before spinning up.
Box
Pin
Contact of sharp edge of
pin thread on box flank
Tripping
• Alternate breaks when tripping so that each joint will be broken-out
every third trip.
• Monitor break-out torque.
• The break-out torque should be less than the make-up torque. High
break-out torque is an indication of down-hole 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 all other Grant Prideco
proprietary connections.
25
11/18/2010 5:37:09 PM
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. Remove
protruding metal with a soft grinding wheel or standard file.
• It is not necessary to use thread protectors when standing the pipe
back.
• Do not use pressed steel thread protectors when standing 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° metal seal when racking back XT-M™ and TurboTorque-M™
connections.
Sharp edge of thread
protector can damage
shoulder.
26
11/18/2010 5:37:09 PM
Downhole Make-up
• Downhole make-up can be detected by high break-out 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.
27
11/18/2010 5:37:10 PM
The following sections provide information and general guidelines regarding the field
inspection of Grant Prideco double shoulder connections and are not intended to
replace NOV Grant Prideco Field Inspection Procedures and Drawings.
Connection type-specific Field Inspection Procedures and connection type and sizespecific Field Inspection Drawings are available direct from NOV Grant Prideco and can
be downloaded from: www.nov.com/grantprideco.com
Make-up Shoulder and Bevel Diameter
• The primary make-up shoulders provide the seal for the connection
(HT®, XT®, GPDS®, TurboTorque®). For XT-M™ and TurboTorque-M™,
the primary seal is the 15° metal seal and the backup seal is the
primary make-up shoulder.
• The primary make-up shoulders and 15° metal seal (XT-M,
TurboTorque-M) should be inspected frequently using current NOV
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” should be removed from either the primary or
secondary make-up shoulder at any one refacing. No more than 1/16”
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 NOV Grant Prideco benchmark and Xmark™ benchmark are
references 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 better.
• When NOV Grant Prideco double shoulder connections are refaced,
the bevel does not need to be remachined.
• 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.
• Refacing is not allowed for metal seals and must be redressed by an
NOV GRP licensed machine shop.
28
11/18/2010 5:37:10 PM
NOV Grant Prideco Benchmark
1
Pin
1
2
3
Box
1
2
3
1
Unlike the API "tangent bar", the NOV Grant Prideco benchmark step
provides a reference that is visible from any position around the
connection circumference.
29
11/18/2010 5:37:10 PM
Checking Pin Length
• The pin length can be checked with a dial indicator or depth
micrometer. 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 than 1/32 inch, the pin must
be recut.
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.
30
11/18/2010 5:37:11 PM
Checking Box Depth
• The box depth can be checked with a dial indicator or depth micrometer. 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.
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.
31
11/18/2010 5:37:11 PM
Special Considerations When Inspecting XT®,
TurboTorque®, XT-M™ and TurboTorque-M™
Connections
• For XT and XT-M, 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 protruding metal should be removed with a soft grinding wheel or a file.
• The XT-M and TurboTorque-M connections contain a 15° metal seal
near the pin and box secondary shoulders. This is the primary sealing
surface for the connection.
– Round pit type defects up to 1/32” in diameter and not
exceeding 1/32” in depth are permissible.
– Multiple pits of this type are acceptable provided there is at
least a 1” separation between pits, along the circumference of
the seal.
– Circumferential lines or marks are acceptable provided they
cannot be detected by rubbing a fingernail across the surface.
– 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.
– XT-M and TT-M connections may not be refaced. Damages
exceeding requirements for the threads, seal and/or shoulder
faces require the connection to be redressed by Grant Prideco
licensed machine shops.
Box Seal
0.188
0.060
0.060
Pin Seal
32
11/18/2010 5:37:11 PM
Thread Form
Pin Cylinder
Dia
Pin
Length
Nose
Dia
Bevel
Dia
Field Inspection Drawing – Pin
33
11/18/2010 5:37:11 PM
TurboTorque® Field Inspection Dimensions – Pin
Bevel Dia
(in)
Pin Cylinder Dia
(in)
Nose Dia2
(in)
TurboTorque 380 TT 0.75 / 3.5 4.679-4.688
4.524-4.681
3.869-3.915
3.388-3.435
TurboTorque 390 TT 0.75 / 3.5 4.554-4.563
4.675-4.832
3.969-4.015
3.496-3.543
TurboTorque 420 TT 0.75 / 3.5 4.679-4.688
5.012-5.169
4.269-4.315
3.788-3.835
TurboTorque 435 TT 0.75 / 3.5
4.616-4.625
5.151-5.308
4.419-4.465
3.942-3.989
5.554-5.563
5.701-5.858
4.919-4.965
4.383-4.430
5.304-5.313
5.960-6.117
5.076-5.122
4.452-4.499
5.741-5.750
6.160-6.317
5.326-5.372
4.665-4.712
4.741-4.750
6.353-6.510
5.576-5.622
4.999-5.046
TurboTorque 585 TT 1.00 / 3.0 5.054-5.063
6.766-6.923
5.926-5.972
5.323-5.370
7.936-8.093
6.962-7.008
6.184-6.231
Connection
Thread1
Radius
Pin Length
(in)
5.429-5.438
Note:
1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco.
2. This reference dimension is not used to determine acceptance or rejection, but to test for pin nose swell
and the need to verify connection length.
34
11/18/2010 5:37:11 PM
TurboTorque-M™ Field Inspection Dimensions –
Pin
Pin Length
(in)
Bevel Dia
(in)
Pin Cylinder
Dia (in)
Nose Dia2
(in)2
TurboTorque-M 380 TT 0.75 / 3.5
5.12 - 5.125
4.524-4.681
3.869-3.915
3.203
4.995 - 5.000
4.675-4.832
3.969-4.015
3.311
5.120 - 5.125
5.012-5.169
4.269-4.315
3.603
5.058 - 5.063
5.151-5.308
4.419-4.465
3.757
TurboTorque-M 485 TT 0.75 / 3.5 5.995 - 6.000
5.701-5.858
4.919-4.965
4.198
5.745 - 5.750
5.960-6.117
5.076-5.122
4.267
6.183 - 6.188
6.160-6.317
5.326-5.372
4.480
5.183 - 5.188
6.353-6.510
5.576-5.622
4.814
TurboTorque-M 585 TT 1.125 / 3.0 5.495 - 5.500
6.766-6.923
5.926-5.972
5.138
Connection
Thread1
Radius
Note:
35
11/18/2010 5:37:11 PM
XT® Field Inspection Dimensions – Pin
Connection
Thread1
Radius
Pin Length
(in)
Bevel Dia
(in)
Pin Cylinder
Dia (in)
Nose Dia2
(in)
XT24
V 042R
3.210-3.219
2.984-3.141
2.490-2.536
2.067-2.114
XT26
V 042R
3.116-3.125
3.203-3.360
2.728-2.774
2.309-2.356
XT29
V 042R
3.647-3.656
3.578-3.735
3.029-3.075
2.594-2.605
XT30
V 042R
3.366-3.375
3.703-3.860
3.174-3.220
2.740-2.787
XT31
V 042R
3.991-4.000
3.859-4.016
3.235-3.281
2.777-2.756
XT34
V 042R
4.147-4.156
4.109-4.266
3.535-3.581
3.063-3.110
XT38
V 042R
4.616-4.625
4.547-4.704
3.844-3.885
3.332-3.378
XT39
V 042R
4.491-4.500
4.770-4.927
4.026-4.072
3.531-3.578
XT40
V 042R
4.491-4.500
5.000-5.157
4.234-4.280
3.735-3.782
XT43
V 042R
3.647-3.656
5.047-5.204
4.385-4.431
3.927-3.974
XT46
V 042R
7.491-7.500
5.918-6.075
4.920-4.966
4.321-4.368
XT50
V 042R
7.291-7.300
6.302-6.459
5.306-5.352
4.743-4.790
XT54
V 042R
6.991-7.000
6.453-6.610
5.564-5.610
5.020-5.067
XT55
V 042R
7.241-7.250
6.857-7.014
5.680-5.726
5.101-5.148
XT57
V 042R
7.241-7.250
6.705-6.862
5.806-5.852
5.262-5.309
XT61
V 042R
6.241-6.250
6.961-7.118
6.213-6.259
5.530-5.577
XT65
V 042R
8.241-8.250
7.703-7.860
6.681-6.727
6.074-6.121
XT69
V 042R
7.804-7.813
7.797-7.954
7.056-7.102
6.476-6.523
Note:
1. Thread form for XT® is proprietary to NOV Grant Prideco.
36
11/18/2010 5:37:11 PM
XT-M™ Field Inspection Dimensions – Pin
Connection
Thread
Radius
Pin Length
(in)
Bevel Dia
(in)
Pin Cylinder
Dia (in)
Nose Dia2
(in)
XT-M24
V 042R
5.054-5.063
2.984-3.141
2.490-2.536
1.882
XT-M26
V 042R
4.991-5.000
3.203-3.360
2.728-2.774
2.124
XT-M29
V 042R
5.491-5.500
3.578-3.735
3.029-3.075
2.393
XT-M31
V 042R
5.866-5.875
3.859-4.016
3.235-3.281
2.576
XT-M34
V 042R
5.991-6.000
4.078-4.235
3.535-3.581
2.873
XT-M38
V 042R
6.491-6.500
4.547-4.704
3.844-3.890
3.146
XT-M39
V 042R
6.241-6.250
4.770-4.927
4.026-4.072
3.360
XT-M40
V 042R
6.491-6.500
5.000-5.157
4.234-4.280
3.550
XT-M43
V 042R
5.616-5.625
5.047-5.204
4.385-4.431
3.742
XT-M46
V 042R
7.491-7.500
5.918-6.075
4.920-4.966
4.136
XT-M50
V 042R
7.291-7.300
6.302-6.459
5.306-5.352
4.558
XT-M57
V 042R
7.241-7.250
6.705-6.862
5.806-5.852
5.076
XT-M61
V 042R
6.241-6.250
6.961-7.118
6.213-6.259
5.345
XT-M65
V 042R
8.241-8.250
7.703-7.860
6.681-6.727
5.889
XT-M67
V 042R
7.991-8.000
7.734-7.891
6.824-6.870
6.048
XT-M69
V 042R
7.804-7.813
7.797-7.954
7.056-7.102
6.291
Note:
1. Thread form for XT-M™ is proprietary to NOV Grant Prideco.
37
11/18/2010 5:37:11 PM
GPDS® Field Inspection Dimensions – Pin
Connection
Thread
Radius
Pin Length
(in)
Bevel Dia
(in)
Pin Cylinder
Dia (in)
Nose Dia1
(in)
GPDS26
V 038R
3.372-3.383
3.250-3.407
2.719-2.765
1.985-2.031
GPDS31
V 038R
3.884-3.895
3.937-4.094
3.235-3.281
2.423-2.469
GPDS38
V 038R
4.396-4.407
4.562-4.719
3.860-3.906
2.954-3.000
GPDS40
V 038R
4.907-4.918
5.000-5.157
4.125-4.171
3.141-3.187
GPDS46
V 038R
4.907-4.918
5.703-5.860
4.678-4.724
3.688-3.734
GPDS50
V 038R
4.907-4.918
6.047-6.204
5.104-5.150
4.110-4.156
GPDS55
V 050
5.420-5.431
6.703-6.860
5.688-5.734
4.548-4.594
GPDS65
V 050
5.420-5.431
7.687-7.844
6.616-6.662
5.469-5.515
Note:
38
11/18/2010 5:37:12 PM
HT® Field Inspection Dimensions – Pin
Connection
Thread
Radius
Pin Length
(in)
Bevel Dia
(in)
Pin Cylinder
Dia (in)
Nose Dia1
(in)
2-3/8 HTSLH90
90°V 084
4.429-4.438
2.984-3.141
2.607-2.653
2.216-2.263
2-7/8 HTPAC
V 076S
4.821-4.830
3.047-3.204
2.406-2.452
1.967-2.014
HT26
V 038R
5.156-5.165
3.296-3.453
2.719-2.765
2.109-2.156
HT31
V 038R
5.334-5.343
3.937-4.094
3.360-3.406
2.574-2.621
HT38
V 038R
5.496-5.505
4.637-4.794
3.880-3.926
3.172-3.219
HT40
V 038R
6.267-6.276
4.859-5.016
4.125-4.171
3.306-3.353
HT46
V 038R
6.282-6.291
5.829-5.986
4.678-4.724
3.859-3.906
HT50
V 038R
6.150-6.159
6.124-6.281
5.094-5.140
4.297-4.344
HT55
V 050
7.338-7.347
6.857-7.014
5.720-5.735
4.667-4.713
HT65
V 050
7.491-7.500
7.547-7.704
6.616-6.662
5.566-5.613
Note:
39
11/18/2010 5:37:12 PM
Counterbore
Wall
Thread Form
Box Depth
Counterbore
Dia
Bevel
Dia
Field Inspection Drawing – Box
40
11/18/2010 5:37:12 PM
TurboTorque® Field Inspection Dimensions – Box
Connection
Thread
Radius1
Box Depth
(in)
Bevel Dia
(in)
Counterbore
Dia (in)
Min C Bore
Wall (in)
TurboTorque 380
TT 0.75/3.5
4.686-4.691
4.524-4.681
3.946-4.008
0.25
TurboTorque 390
TT 0.75/3.5
4.561-4.566
4.675-4.832
4.046-4.108
0.25
TurboTorque 420
TT 0.75/3.5
4.686-4.691
5.012-5.169
4.346-4.408
0.25
TurboTorque 435
TT 0.75/3.5
4.623-4.628
5.151-5.308
4.496-4.558
0.313
TurboTorque 485
TT 0.75/3.5
5.561-5.566
5.701-5.585
4.996-5.058
0.313
TurboTorque 500
TT 1.00/3.0
5.311-5.316
5.960-6.117
5.158-5.220
0.313
TurboTorque 525
TT 1.00/3.0
5.748-5.753
6.160-6.317
5.408-5.470
0.313
TurboTorque 550
TT 1.00/3.0
4.748-4.753
6.353-6.510
5.658-5.720
0.313
TurboTorque 585
TT 1.00/3.0
5.061-5.066
6.766-6.923
6.008-6.070
0.313
TurboTorque 690
TT 1.25/3.0
5.438-5.443
7.936-8.093
7.133-7.195
0.313
Note:
41
11/18/2010 5:37:12 PM
TurboTorque-M™ Field Inspection Dimensions –
Box
Box Depth
(in)
Bevel Dia
(in)
Counterbore
Dia (in)
Min C Bore
Wall (in)
TurboTorque-M 380
5.123-5.128
4.524-4.681
3.946-4.008
0.25
TurboTorque-M 390
4.998-5.003
4.675-4.832
4.046-4.108
0.25
TurboTorque-M 420
5.123-5.128
5.012-5.169
4.346-4.408
0.25
TurboTorque-M 435
5.061-5.066
5.151-5.308
4.496-4.558
0.313
TurboTorque-M 485
5.998-6.003
5.701-5.858
4.996-5.058
0.313
TurboTorque-M 500
5.750-5.755
5.960-6.117
5.158-5.220
0.313
TurboTorque-M 525
6.188-6.193
6.160-6.317
5.408-5.470
0.313
TurboTorque-M 550
5.188-5.193
6.353-6.510
5.658-5.720
0.313
TurboTorque-M 585
5.500-5.505
6.766-6.923
6.008-6.070
0.313
Connection
Thread
Radius1
Note:
42
11/18/2010 5:37:12 PM
XT® Field Inspection Dimensions – Box
Connection
Thread
Radius
Box Depth
(in)
Bevel Dia
(in)
Counterbore
Dia (in)
Min C Bore
Wall (in)
XT24
V 042R
3.217-3.222
2.984-3.141
2.593-2.655
0.188
XT26
V 042R
3.123-3.128
3.203-3.360
2.831-2.893
0.188
XT29
V 042R
3.654-3.659
3.578-3.735
3.132-3.194
0.188
XT30
V 042R
3.373-3.378
3.703-3.860
3.267-3.329
0.188
XT31
V 042R
3.998-4.003
3.859-4.016
3.342-3.404
0.188
XT34
V 042R
4.154-4.159
4.109-4.266
3.638-3.700
0.188
XT38
V 042R
4.623-4.628
4.547-4.704
3.947-4.009
0.250
XT39
V 042R
4.498-4.503
4.770-4.927
4.121-4.183
0.250
XT40
V 042R
4.498-4.503
5.000-5.157
4.324-4.386
0.250
XT43
V 042R
3.654-3.659
5.047-5.204
4.488-4.550
0.313
XT46
V 042R
7.505-7.510
5.918-6.075
5.071-5.133
0.313
XT50
V 042R
7.305-7.310
6.302-6.459
5.409-5.471
0.313
XT54
V 042R
7.005-7.010
6.453-6.610
5.667-5.729
0.313
XT55
V 042R
7.255-7.260
6.857-7.014
5.783-5.845
0.313
XT57
V 042R
7.255-7.260
6.705-6.862
5.909-5.971
0.313
XT61
V 042R
6.255-6.260
6.961-7.118
6.316-6.378
0.313
XT65
V 042R
8.255-8.260
7.703-7.860
6.784-6.846
0.313
XT69
V 042R
7.818-7.823
7.797-7.954
7.159-7.221
0.313
Note:
1. Thread form for XT® is proprietary to NOV Grant Prideco.
43
11/18/2010 5:37:12 PM
XT-M™ Field Inspection Dimensions – Box
Connection
Thread
Radius
Box Depth
(in)
Bevel Dia
(in)
Counterbore
Dia (in)
Min C Bore
Wall (in)
XT-M24
V 042R
5.068-5.073
2.984-3.141
2.593-2.655
0.188
XT-M26
V 042R
5.005-5.010
3.203-3.360
2.831-2.893
0.188
XT-M29
V 042R
5.505-5.510
3.578-3.735
3.132-3.194
0.188
XT-M31
V 042R
5.880-5.885
3.859-4.016
3.342-3.404
0.188
XT-M34
V 042R
6.005-6.010
4.078-4.235
3.638-3.700
0.250
XT-M38
V 042R
6.505-6.510
4.547-4.704
3.947-4.009
0.250
XT-M39
V 042R
6.255-6.260
4.770-4.927
4.129-4.191
0.250
XT-M40
V 042R
6.505-6.510
5.000-5.157
4.358-4.386
0.250
XT-M43
V 042R
5.630-5.635
5.047-5.204
4.488-4.550
0.313
XT-M46
V 042R
7.505-7.510
5.918-6.075
5.071-5.133
0.313
XT-M50
V 042R
7.305-7.310
6.302-6.459
5.409-5.471
0.313
XT-M57
V 042R
7.255-7.260
6.705-6.862
5.909-5.971
0.313
XT-M61
V 042R
6.255-6.260
6.961-7.118
6.316-6.378
0.313
XT-M65
V 042R
8.255-8.260
7.703-7.860
6.784-6.846
0.313
XT-M67
V 042R
8.005-8.010
7.734-7.891
6.927-6.989
0.313
XT-M69
V 042R
7.818-7.823
7.797-7.954
7.159-7.221
0.313
Note:
1. Thread form for XT-M™ is proprietary to NOV Grant Prideco.
44
11/18/2010 5:37:12 PM
GPDS® Field Inspection Dimensions – Box
Connection
Thread
Radius
Box Depth
(in)
Bevel Dia
(in)
Counterbore
Dia (in)
Min C Bore
Wall (in)
GPDS26
V 038R
3.378-3.389
3.250-3.407
2.899-2.961
0.188
GPDS31
V 038R
3.890-3.901
3.937-4.094
3.414-3.476
0.188
GPDS38
V 038R
4.402-4.415
4.562-4.719
4.039-4.101
0.250
GPDS40
V 038R
4.915-4.927
5.000-5.157
4.305-4.367
0.250
GPDS46
V 038R
4.915-4.927
5.703-5.860
4.867-4.929
0.313
GPDS50
V 038R
4.915-4.927
6.047-6.204
5.274-5.336
0.313
GPDS55
V 050
5.427-5.439
6.703-6.860
5.867-5.929
0.313
GPDS65
V 050
5.427-5.439
7.687-7.844
6.805-6.867
0.313
Note:
45
11/18/2010 5:37:12 PM
HT® Field Inspection Dimensions – Box
Connection
Thread
Radius
Box Depth
(in)
Bevel Dia
(in)
Counterbore
Dia (in)
Min C Bore
Wall (in)
2-3/8 HTSLH90
90°V 084
4.443-4.448
2.984-3.141
2.727-2.789
0.094
2-7/8 HTPAC
V 076S
4.835-4.840
3.047-3.204
2.539-2.601
0.188
HT26
V 038R
5.168-5.173
3.296-3.453
2.907-2.969
0.188
HT31
V 038R
5.351-5.356
3.937-4.094
3.422-3.484
0.188
HT38
V 038R
5.510-5.515
4.637-4.794
4.047-4.109
0.313
HT40
V 038R
6.281-6.286
4.859-5.016
4.313-4.375
0.313
HT46
V 038R
6.296-6.301
5.829-5.986
4.875-4.937
0.313
HT50
V 038R
6.164-6.169
6.124-6.281
5.282-5.344
0.313
HT55
V 050
7.352-7.357
6.857-7.014
5.875-5.937
0.313
HT65
V 050
7.504-7.509
7.547-7.704
6.813-6.875
0.313
Note:
46
11/18/2010 5:37:12 PM
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 high-angle 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. NOV Grant Prideco offers
three types of HWDP configurations to meet the challenge of severe
drilling conditions.
Standard Heavy Weight Drill Pipe
18°
24”
HEAVY WEIGHT
DRILL PIPE
· Standard HWDP – Developed to provide a gradual transition from the
heavy drill collar to the relatively lightweight drill pipe.
B
Elevator Upset
Diameter
C
Wear Section
Upset Diameter
26”
31’
Nominal
Length
A
Nominal Size
B
Upset Diameter
D
Tool Joint
OD
24”
18°
47
11/18/2010 5:36:06 PM
• 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
p
D
Box Tool
Joint
24”
B
Elevator
Upset
Diameter
C
Spiral
Upset
26”
31’
Nominal
Length
C
Center
Spiral
Upset
26”
C
Spiral
Upset
26”
A
Nominal Size
B
Upset Diameter
24”
D
Pin Tool
Joint
48
11/18/2010 5:36:07 PM
Heavy Weight Drill Pipe (HWDP)
· 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”
A
Nominal
Size
31’
Nominal
Length
C
Spiral
Upset
21'4”
9”
D
Pin Tool
Joint
24”
49
TAB 3 RSHandbook_Heavyweight.indd 49
11/18/2010 5:37:31 PM
2 1/16
2 1/4
2 9/16
2 3/4
3
3 1/4
4
4 1/2
3 1/2
3 1/2
4
4 1/2
5
5 1/2
5 7/8
6 5/8
1.063
0.938
1.125
1.000
0.875
0.719
0.625
0.719
(in)
Wall
Thickness
18.574
14.542
15.463
12.566
9.965
7.411
5.645
6.282
(sq in)
Area
22.476
15.630
14.342
10.681
7.698
5.225
3.490
3.702
7 1/8
6 3/8
6
5 1/2
5
4 1/2
4
4
6 15/16
6
5 11/16
5 1/8
4 11/16
4 3/16
3 7/8
3 7/8
Section
Spiral
End
Modulus Upset Dia Upset Dia
(C)
(B)
(cu in)
(in)
(in)
Notes: Torque figures with * indicate reduced make up for typically chamfered connection.
(in)
ID
Nominal
Size
(A)
Nominal Dimensions
Tube
1,021,600
799,800
850,400
691,200
548,100
407,600
310,500
345,500
(lb)
Tensile
Yield
118,900
82,700
75,900
56,500
40,700
27,600
18,500
19,600
(ft-lb)
Torsional
Yield
Mechanical
Properties
7 1/4
5 1/2 FH
HT®55
6 5/8 FH
8
7
6 5/8
XT®57
6 1/4
5 1/4
4 7/8
NC 40 (4 FH)
XT® 39
NC 46 (4 IF)
4 3/4
4 7/8
4 7/8
NC 38 (3 1/2 IF)
HT® 38
XT® 39
NC 50 (4 1/2 IF)
HT® 50
4 3/4
(in)
OD
(D)
NC 38 (3 1/2 IF)
Connection
Size and Type
4 1/2
4
3 1/4
3
2 3/4
2 9/16
2 1/4
2 1/16
(in)
ID
Tool Joint
Nominal Dimensions
Standard Heavy Weight Drill Pipe
1,896,100
1,403,100
1,778,300
1416,200
1,183,900
838,300
729,700
790,900
790,900
871,700
867,100
(lb)
Tensile
Yield
50.38
88,000
106,200
71.43
57.42
61.63
41.45
29.92
28.40
23.48
23.96
23.96
25.65
(lb)
Per
Foot
44,900
78,500
115,100
Assembly
2,214
1,780
1,911
1,562
1,285
928
880
728
743
743
795
50,500
63,700*
41,200
69,000*
30,000
53,300
23,200
14,600
22,200
11,500
20,500
24,400
11,500
Make-up
Per
31 ft Joint Torque
(lb)
(ft-lb)
Adjusted
Weight
58,000
88,000
27,800
37,000
19,200
34,200
40,700
19,200
(ft-lb)
Torsional
Yield
Mechanical
Properties
Dimensional Data - Range II
50
11/18/2010 5:37:38 PM
2 1/4
2 9/16
2 3/4
3
3 1/4
4
3 1/2
4
4 1/2
5
5 1/2
5 7/8
1.063
0.938
1.125
1.000
0.875
0.719
0.625
0.719
(in)
Wall
Thickness
18.574
14.542
15.463
12.566
9.965
7.411
5.645
6.282
(sq in)
Area
22.476
15.630
14.342
10.681
7.698
5.225
3.490
3.702
7 1/8
6 3/8
6
5 1/2
5
4 1/2
4
4
6 15/16
6
5 11/16
5 1/8
4 11/16
4 3/16
3 7/8
3 7/8
Section
Spiral
End
(C)
(B)
(cu in)
(in)
(in)
Notes: Torque figures with * indicate reduced make up for typically chamfered connection.
4 1/2
2 1/16
3 1/2
6 5/8
(in)
ID
Nominal
Size
(A)
Nominal Dimensions
Tube
1,021,600
799,800
850,400
691,200
548,100
407,600
310,500
345,500
(lb)
Tensile
Yield
118,850
82,700
75,900
56,500
40,700
27,600
18,500
19,600
(ft-lb)
Torsional
Yield
Mechanical
Properties
7 1/4
5 1/2 FH
HT® 55
6 5/8 FH
8
7
6 5/8
XT®57
6 1/4
5 1/4
4 7/8
NC 40 (4 FH)
XT® 39
NC 46 (4 IF)
4 3/4
4 7/8
4 7/8
NC 50 (4 1/2 IF)
HT® 50
2 1/16
4 3/4
NC 38 (3 1/2 IF)
NC 38 (3 1/2 IF)
HT® 38
XT® 39
4 1/2
4
3 1/4
3
2 3/4
2 9/16
2 1/4
(in)
OD
(D)
(in)
Connection
Size and
Type
ID
Tool Joint
Nominal Dimensions
TRI-SPIRAL™ Heavy Weight Drill Pipe
1,896,100
1,403,100
1,778,300
1416,200
44,900
1,183,900
88,000
106,200
78,500
115,100
58,000
88,000
27,800
37,000
19,200
34,200
40,700
19,200
(ft-lb)
Torsional
Yield
838,300
729,700
790,900
790,900
871,700
867,100
(lb)
Tensile
Yield
Mechanical
Properties
Assembly
74.67
57.42
63.78
52.34
43.31
31.51
29.99
24.88
25.36
25.36
27.05
(in)
Per
foot
2,315
1,780
1,977
1,623
1,343
977
930
771
786
786
839
Per
31 ft
Joint
(lb)
Adjusted
Weight
50,500
63,700*
41,200
69,000*
30,000
53,300
23,200
14,600
22,200
11,500
20,500
24,400
11,500
(ft-lb)
Make-up
Torque
51
11/18/2010 5:37:38 PM
1
2 3/4
3
3 1/4
4
4 1/2
5
5 1/2
5 7/8
1.063
0.938
1.125
1.000
0.875
0.719
0.625
0.594
(in)
Wall
Thickness
18.574
14.542
15.463
12.566
9.965
7.411
5.645
4.840
(sq in)
Area
22.476
16.630
14.342
10.681
7.698
5.225
3.490
2.687
7 1/8
6 3/8
6
5 1/2
5
4 1/2
4
3 5/16
6 3/4
6
5 5/8
5 1/8
4 5/8
4 1/8
3 5/8
N/A
Section
Spiral
End
(C)
(B)
(cu in)
(in)
(in)
1,021,600
799,800
850,400
691,200
548,100
407,600
310,500
532,400
(lb)
Tensile
Yield
118,900
82,700
75,900
56,500
40,700
27,600
18,500
28,400
(ft-lb)
Torsional
Yield
Mechanical
Properties
7
5 1/2 FH
HT® 55
6 5/8 FH
4 1/2
4
3 1/4
3
2 3/4
2 9/16
2 1/4
2
(in)
1,896,100
1,403,100
1,778,300
1,416,200
1,183,900
838,300
729,700
790,000
790,900
871,400
407,000
(lb)
Tensile
Yield
88,000
106,200
53,000
99,000
57,800
88,800
44,900
20,900
40,800
22,900
34,200
40,700
12,000
(ft-lb)
Torsional
Yield
Mechanical
Properties
2. Reduced makeup for typically chamfered connection.
8
7
6 5/8
XT® 57
6 1/4
5
NC 40 (4 FH)
XT® 39
NC 46 (4 IF)
4 7/8
NC 50 (4 1/2 IF)
HT® 50
3 7/8
SLH90
NC 38 (3 1/2 IF)
HT® 38
HT® 39
(in)
OD
(D)
ID
Tool Joint
Nominal Dimensions
Connection
Size and
Type
Notes: 1. 3-3/16 inch Spiral-Wate, previously referred to as 2-7/8 inch, is only manufactured as an integral (non-welded) design.
4 1/2
2 9/16
4
6 5/8
2 1/4
2
(in)
ID
3 1/2
3 3/16
(A)
Nominal
Size
Nominal Dimensions
Tube
SPIRAL-WATE® Drill Pipe mechanical properties
Assembly
82.12
65.38
69.09
59.16
49.53
28.90
30.39
19.48
(lb)
Per
foot
2,546
2,027
2,141
1,834
1,535
896
942
604
Per
31 ft
Joint
(lb)
Adjusted
Weight
50,500
63,7002
29,200
46,3002
30,000
53,30002
23,200
12,600
24,5002
13,100
20,500
24,400
6,300
(ft-lb)
Make-up
Torque
52
11/18/2010 5:37:38 PM
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
high-quality 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.
Hardbanding Repair and Re-Application
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 NOV Grant Prideco licensed repair facility can provide welding repair
service to factory specifications to ensure weld area integrity. Contact your
representative today, or visit www.GrantPrideco.com for more information.
53
11/18/2010 5:36:11 PM
Care and Maintenance
Bending Strength Ratios
Sizes less than six inches should have a Bending Strength Ratio (BSR) of
2.25:1 to 2.75:1. For conditions that require high RPM and small collars
compared to the hole size, use 2.25:1 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.
The current industry BSR calculation for single-shoulder rotary-shouldered
connections are not applicable for double-shouldered connections (HT®,
XT®, GPDS®) as appropriate target ranges are yet to be defined due to limited industry experience and testing of available types/sizes.
Slip and Elevator Grooves
20”
A
R
Cold Work
Shoulder Area
20”
16”
B
2” Radius
3”
3”
1” Radius
18”
18”
C
2” Radius
3”
3”
Slip Grooved
Elevator and Slip Grooved
(zip grooved)
54
11/18/2010 5:36:11 PM
Materials Mechanical Properties
Drill Collar
Diameter
Min. Yield
Strength
Min. Tensile
Strength
Min
Hardness
(BHN)
(in)
(psi)
(psi)
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
Collar
Diameter
Elevator
Recess
Diameter
Slip
Recess
Diameter
Elevator
Recess
Radius
A
(in)
B
(in)
C
(in)
R
(in)
4 1/8
3 11/16
3 3/4
1/8
4 3/4
4 1/4
4 3/8
1/8
1/8
5
4 1/2
4 5/8
5 1/4
4 3/4
4 7/8
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
6 3/4
6
6 1/4
3/16
7
6 1/4
6 1/2
3/16
7 1/4
6 1/2
6 3/4
3/16
3/16
7 3/4
7
7 1/4
8
7 1/4
7 1/2
3/16
8 1/4
7 1/2
7 3/4
3/16
3/16
8 1/2
7 3/4
8
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
Notes: On rework, minimum distance from face to box elevator should or end of hardbanding should be a
length equivalent to depth of box or boreback plus two inches.
55
TAB 4 RSHandbook_Drill Collar.indd 55
11/18/2010 5:38:36 PM
Recommended Minimum Make-up Torque for
Rotary-Shouldered Drill Collar Connections
Size
Connection
Type
OD (in)
3
API
NC 23
3 1/8
3 1/4
3
PAC 3
2 7/8
3 1/8
3 1/4
2 3/8
API
2 3/8
API IF or
NC 26 or
Slim Hole
2 7/8
3 1/2
2 7/8
Extra Hole or
Dbl. Streamline
or
Mod. Open
3 1/2
3 3/4
3 3/4
3 7/8
4 1/8
3 7/8
2 7/8
API
3 1/2
4 1/8
API IF or
NC 31 or
Slim Hole
4 1/4
4 1/2
Bore of Drill Collar (in)
1
1 1/4
*2,500
*2,500
*3,300
*3,300
*3,300
*3,300
*4474
*4474
4,000
3,400
5423
*4610
*3,800
*5152
*5,000
6644
5,200
7050
*4,600
*6237
5,500
7457
*4,100
*5559
*5,400
*7186
*8,100
*10847
*4,600
*6237
*7,400
*9897
*8,800
*11931
10,300
13558
4 1/2
API
NC 35
4 3/4
5
4 1/4
4 1/2
3 1/2
4
3 1/2
Extra Hole or
Slim Hole or
Mod. Open
4 3/4
5
5 1/4
Refer to pages 68-69 for notes.
56
11/18/2010 5:38:41 PM
Foot-Pounds
Newton-Meters
1 1/2
*2,500
*3,300
2,600
3525
2,600
3525
*3,800
*5152
4,200
5694
4,200
5694
*4,600
*6237
4,700
6372
*4,100
*5559
*5,400
*7186
*8,100
*10847
*4,600
*6237
*7,400
*9897
*8,900
*11931
9,300
12609
1 3/4
2,900
3932
2,900
3932
2,900
3932
3,700
5017
3,700
5017
*4,100
*5559
*5,400
7186
7,400
10033
*4,600
*6237
*7,400
*9897
8,200
10982
8,200
10982
*9,000
*12067
12,300
16405
12,300
16405
*5,200
6915
*8,500
*11389
*12,000
*16134
13,300
17897
13,400
17897
2
2 1/4
*4,600
*6237
6,900
9220
6,900
9220
6,900
9220
*9,000
*12067
*10,800
14643
10,800
14643
*5,200
6915
*8,500
11389
11,800
15863
11,800
15863
11,800
15863
*9,000
*12067
9,200
12474
9,200
12474
*5,200
6915
*8,500
11389
10,100
13558
10,100
13558
10,100
13558
2 1/2
2 13/16
7,400
10033
7,400
10033
7,400
10033
*5,200
6915
*8,300
11118
8,300
11118
8,300
11118
8,300
11118
57
11/18/2010 5:38:41 PM
Size
Connection
Type
OD (in)
1
1 1/4
1 1/2
4 3/4
3 1/2
API
4 1/2
API IF or
NC 38 or
Slim Hole
5
5 1/4
5 1/2
4 3/4
5
3 1/2
H 904
5 1/4
5 1/2
5
4
API
4
4 1/2
Full Hole
NC 40 or
Mod Open or
Dbl. Streamline
5 1/4
5 1/2
5 3/4
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
58
11/18/2010 5:38:41 PM
Foot-Pounds
Newton-Meters
1 3/4
*10,000
13423
*13,900
*18710
16,200
21693
16,200
21693
*8,800
*11796
*12,800
*17219
*17,100
*22913
18,500
25083
*10,900
*14643
*15,300
*20473
*20,000
*26710
20,500
27659
20,500
27659
2
*10,000
13423
*13,900
*18710
14,600
19795
14,600
19795
*8,800
*11796
*12,800
*17219
16,900
22642
16,900
22642
*10,900
*14643
*15,300
*20473
18,900
25218
18,900
25218
18,900
25218
*12,600
*16948
*17,400
*23456
*22,300
*30235
23,700
31862
23,700
31862
*15,600
*20880
*20,600
*27523
23,700
31726
23,700
31726
2 1/4
2 1/2
*10,000
*10,000
13423
13423
12,900
11,000
17354
14778
12,900
11,000
17354
14778
12,900
11,000
17354
14778
*8,800
*8,800
*11796
*11796
*12,800
12,800
*17219
17219
15,100
13,200
20337
17761
15,100
13,200
20337
17761
*10,900
*10,900
*14643
*14643
*15,300
15,000
*20473
20066
17,000
15,000
22913
20066
17,000
15,000
22913
20066
17,000
15,000
22913
20066
*12,600
*12,600
*16948
*16948
*17,400
*17,400
*23456
*23456
21,500
19,500
*29150
26303
21,700
19,400
29150
26303
21,700
19,500
29150
26303
*15,600
*15,600
*20880
*20880
*20,600
19,600
*27523
26303
21,700
19,600
29286
26303
21,700
19,600
29286
26303
2 13/16
*8,300
*11253
8,300
11253
8,300
11253
8,300
11253
*8,800
*11796
10,400
14101
10,400
14101
10,400
14101
*10,900
*14643
12,100
16405
12,100
16405
12,100
16405
12,100
16405
*12,600
*16948
*16,500
22371
16,500
22371
16,500
22371
16,500
22371
*15,600
*20880
16,600
21964
*16,600
21964
16,600
21964
59
11/18/2010 5:38:41 PM
Size
Connection
Type
OD in
1 1/2
5 3/4
6
API
NC 44
6 1/4
6 1/2
5 1/2
5 3/4
4 1/2
API Full Hole
6
6 1/4
6 1/2
1 3/4
2
*20,900
*27930
25,500
33895
25,500
33895
25,500
33895
*13,000
*17490
*18,100
*24269
*23,600
*31591
27,300
36607
27,300
36607
5 3/4
4 1/2
API
4
4 1/2
5
4 1/2
Extra Hole
NC 46
API IF
Semi F
Dbl Streamline
Mod Open
6
6 1/4
6 1/2
6 3/4
5 3/4
6
4 1/2
H 904
6 1/4
6 1/2
6 3/4
6 1/4
6 1/2
5
H 904
6 3/4
7
60
11/18/2010 5:38:41 PM
Foot-Pounds
Newton-Meters
2 1/4
*20,900
*27930
23,500
31591
23,500
31591
23,500
31591
*13,000
*17490
*18,100
*24269
*23,600
*31591
*25,300
33895
25,300
33895
*17,700
*23862
*23,400
31455
28,000
37963
28,000
37963
28,000
37963
*18,000
*23862
*23,700
*31726
28,700
38641
28,700
38641
28,700
38641
*25,400
*33895
*31,900
*42708
35,300
47453
35,300
47453
2 1/2
*20,900
*27930
21,300
28743
21,300
28743
21,300
28743
*13,000
*17490
*18,100
*24269
23,000
30913
23,000
30913
23,000
30913
*17,700
*23862
*23,400
31455
25,700
34573
25,700
34573
25,700
34573
*18,000
*23862
*23,700
*31726
26,400
35251
26,400
35251
26,400
35251
*25,400
*33895
*31,900
*42708
32,800
44742
32,800
44742
2 13/16
3
18,100
24405
18,200
24405
18,200
24405
18,200
24405
*13,000
*13,000
*17490
*17490
*18,100
17,900
*24269
23998
19,900
17,900
26845
23998
19,900
17,900
26845
23998
19,900
17,900
26845
23998
*17,700
*17,700
*23862
*23862
22,400
20,300
30099
27388
22,400
20,300
30099
27388
22,400
20,300
30099
27388
22,400
20,300
30099
27388
*18,000
*18,000
*23862
*23862
23,200
21,100
31184
28472
23,200
21,100
31184
28472
23,200
21,100
31184
28472
23,200
21,100
31184
28472
*25,400
*25,400
*33895
*33895
29,400
27,200
39997
36607
29,400
27,200
39997
36607
29,400
27,200
39997
36607
3 1/4
61
11/18/2010 5:38:41 PM
Size
Connection
Type
OD (in)
2
6 1/4
4 1/2
API
5
5
5 1/2
API IF or
NC 50 or
Extra Hole or
Mod Open or
Dbl. Streamline
or Semi IF
6 1/2
6 3/4
7
7 1/4
7 1/2
6 3/4
7
5 1/2
H 904
7 1/4
7 1/2
6 3/4
7
5 1/2
API Regular
7 1/4
7 1/2
7
7 1/4
5 1/2
API Full Hole
7 1/2
7 3/4
7 1/4
7 1/2
API
NC 56
7 3/4
8
2 1/4
2 1/2
*23,000
*23,000
*30913
*30913
*29,700
*29,700
39997
*39997
*36,700
35,800
*48809
48132
38,400
35,800
51521
48132
38,400
35,800
51521
48132
38,400
35,800
51521
48132
*34,500
*34,500
*46098
46640
*42,000
40,100
*56266
54233
42,700
40,100
57622
54233
42,700
40,100
57622
54233
*31,900
*31,900
*42708
*42708
*39,400
*39,400
*52877
*52877
42,400
39,900
56944
53555
42,400
39,900
56944
53555
*32,800
*44064
*41,000
*54911
*49,700
66435
51,700
69825
*40,500
54233
*49,100
*65757
52,100
69147
52,100
69147
62
11/18/2010 5:38:41 PM
Foot-Pounds
Newton-Meters
2 13/16
*23,000
*30913
*29,700
*39997
32,300
43657
32,300
43386
32,300
43386
32,300
43386
*34,500
*46098
36,500
49487
36,500
49487
36,500
49487
*31,900
*42708
36,200
48809
36,200
48809
36,200
48809
32,800
44064
*41,000
*54911
47,800
63723
47,800
63723
*40,500
*54233
48,200
65079
48,200
65079
48,200
65079
3
*23,000
*30913
*29,700
*39997
30,000
40675
30,000
40675
30,000
40675
30,000
40675
34,100
46098
34,100
46098
34,100
46098
34,100
46098
*31,900
*42708
33,900
45420
33,900
45420
33,900
45420
32,800
44064
*41,000
*54233
45,200
61012
45,200
61012
*40,500
*54233
45,700
61690
45,700
61012
45,700
61012
3 1/4
3 1/2
*23,000
*30913
26,700
35929
26,700
35929
26,700
35929
26,700
35929
26,700
35929
3 3/4
*32,800
*44064
*41,000
*54911
41,500
56266
41,500
56266
*40,500
*54233
42,100
56944
42,100
56944
42,100
56944
63
11/18/2010 5:38:41 PM
Size
Connection
Type
OD (in)
2
7 1/2
7 3/4
6 5/8
API Regular
8
8 1/4
7 1/2
7 3/4
6 5/8
H 904
8
8 1/4
8
8 1/4
API
NC 61
8 1/2
8 3/4
9
8
8 1/4
8 1/2
5 1/2
API IF
8 3/4
9
9 1/4
2 1/4
2 1/2
*46,400
*62368
*55,600
*74570
57,400
77282
57,400
77282
*46,500
*62368
*55,700
*74570
60,300
*80671
60,300
80671
*55,100
*73214
*65,400
*86772
72,700
97619
72,700
97619
72,700
97619
*56,600
*75926
*67,100
*89484
74,600
100331
74,600
100331
74,600
100331
74,000
100331
8 1/2
8 3/4
6 5/8
API Full Hole
9
9 1/4
9 1/2
64
11/18/2010 5:38:41 PM
Foot-Pounds
Newton-Meters
2 13/16
*46,400
*62368
53,300
71858
53,300
71858
53,300
71858
*46,500
*62368
55,700
*74570
*56,300
*75926
56,300
75926
*55,100
*73214
*65,400
*86772
68,400
92196
68,400
92196
68,400
92196
*56,600
*75926
*67,100
*89484
70,300
94907
70,300
94907
70,300
94907
70,300
94907
*67,800
*90840
*79,500
*105754
84,000
112533
84,000
112533
84,000
112533
3
*46,400
*62368
50,700
67791
50,700
67791
50,700
67791
*46,500
*62368
53,600
71858
53,600
71858
53,600
71858
*55,100
*73214
*65,400
*86772
65,600
88128
65,600
88128
65,600
88128
*56,600
*75926
*67,100
*89484
67,400
90840
67,400
90840
67,400
90840
67,400
90840
*67,800
*90840
*79,500
*105754
80,100
108465
80,100
108465
80,100
108465
3 1/4
3 1/2
*46,400
*62368
46,900
63723
46,900
63723
46,900
63723
*46,500
*62368
49,900
67113
49,900
67113
49,900
67113
*55,100
*73214
*61,600
82705
61,600
82705
61,600
82705
61,600
82705
*56,600
*56,600
*75926
*75926
63,400
59,000
85417
79993
63,400
59,000
85417
79993
63,400
59,000
85417
79993
63,400
59,000
85417
79993
63,400
59,000
85417
79993
*67,800
*67,800
*90840
*90840
76,700
72,100
103042
97619
76,700
72,100
103042
97619
76,700
72,100
103042
97619
76,700
72,100
103042
97619
3 3/4
67,200
90162
67,200
90162
67,200
90162
67,200
90162
67,200
90162
65
11/18/2010 5:38:42 PM
Size
Connection
Type
OD (in)
2
2 1/4
2 1/2
9
9 1/4
9 1/2
API
NC 70
9 3/4
10
10 1/4
10
10 1/4
API
NC 77
10 1/2
10 3/4
11
8
7
H 904
8 1/4
8 1/2
8 1/2
8 3/4
7 5/8
API Regular
9
9 1/4
9 1/2
9
7 5/8
H 904
9 1/4
9 1/2
66
11/18/2010 5:38:42 PM
Foot-Pounds
Newton-Meters
2 13/16
*75,800
*101686
*88,800
*119312
*102,400
*136938
108,800
145073
108,800
145073
108,800
145073
*53,500
*71858
*63,700
*85417
72,100
96941
3
3 1/4
3 1/2
*75,800
*75,800
*75,800
*101686
*101686
*101686
*88,800
*88,800
*88,800
*119312
*119312
*119312
*102,400
101,100
96,200
*136938
135582
128803
105,700
101,100
96,200
142361
135582
128803
105,700
101,100
96,200
142361
135582
128803
105,700
101,100
96,200
142361
135582
128803
*108,200
*108,200
*108,200
*145073
*145073
*145073
*124,100
*124,100
*124,100
*165410
*165410
*165410
*140,500
*140,500
135,100
*187103
*187103
180324
145,500
140,500
135,100
193882
187103
180324
145,500
140,500
135,100
193882
187103
180324
*53,500
*53,500
*53,500
*71858
*71858
*71858
*63,700
*63,700
61,000
*85417
*85417
*82027
69,300
69,300
61,000
92874
88128
82027
*60,400
*60,400
*60,400
*81349
*81349
*81349
*72,200
*72,200
*72,200
*96263
*96263
*96263
*84,400
*84,200
79,500
*112533
*112533
107110
88,600
84,200
79,500
119312
112532
107110
88,600
84,200
79,500
119312
112532
107110
*73,000
*73,000
*73,000
*97619
*97619
*97619
*86,000
*86,000
*86,000
*115922
*115922
*115922
*99,500
*99,500
*99,500
*132870
*132870
*132870
3 3/4
*75,800
*101686
*88,800
*119312
91,000
122024
91,000
122024
91,000
122024
91,000
122024
*108,200
*145073
*124,100
*165410
129,400
173545
129,400
173545
129,400
173545
*60,400
*81349
*72,200
*96263
74,500
100331
74,500
100331
74,500
100331
*73,000
*97619
*86,000
*115922
96,300
129481
67
11/18/2010 5:38:42 PM
Size
Connection
Type
OD (in)
2
2 1/4
2 1/2
10
8 5/8
API Regular
10 1/4
10 1/2
10 1/4
8 5/8
H 904
10 1/2
7
H 904
(with low
torque face)
8 3/4
9
9 1/4
7 5/8
API Regular
(with low
torque face)
9 1/2
9 3/4
10
9 3/4
7 5/8
H 904
(with low
torque face)
10
10 1/4
10 1/2
8 5/8
API Regular
(with low
torque face)
10 3/4
11
10 3/4
8 5/8
H 904
(with low
torque face)
11
11 1/4
Notes: 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.
Normal torque range is tabulated value plus 10%. Higher torque values may be used under extreme
conditions.
68
11/18/2010 5:38:42 PM
Foot-Pounds
Newton-Meters
2 13/16
*68,100
*91518
74,200
100331
3
3 1/4
3 1/2
*109,300
*109,300
*109,300
*146428
*146428
*146428
*125,300
*125,300
*125,300
*166766
*166766
*166766
141,100
136,100
130,800
188459
181680
174901
*113,500
*113,500
*113,500
*152530
*152530
*152530
*130,100
*130,100
*130,100
*174223
*174223
*174223
*68,100
67,300
62,800
*91518
90162
84061
71,400
67,300
62,800
96263
90162
84061
*73,100
*73,100
*73,100
*97619
*97619
*97619
*86,500
*86,500
82,500
*115245
*115245
111177
91,800
87,300
82,500
123379
117956
111177
91,800
87,300
82,000
123379
117956
111177
*91,700
*91,700
*91,700
*123379
*123379
*123379
*106,300
*106,300
104,200
*142361
*142361
140327
113,900
109,200
104,200
152530
146428
140327
113,900
109,200
104,200
152530
146428
140327
*112,900
*112,900
*112,900
*151852
*151852
*151852
*130,700
*130,700
*130,700
*174901
*174901
*174901
*93,000
*93,000
*93,000
*125413
*125413
*125413
*110,800
*110,800
*110,800
*149140
*149140
*149140
*129,200
*129,200
*129,200
*173545
*173545
*173545
3 3/4
*109,300
*146428
*125,300
*166766
125,000
166766
*113,500
*152530
*130,100
*174223
*73,100
*97619
77,300
104398
77,300
104398
77,300
104398
*91,700
*123379
98,800
132870
98,800
132870
98,800
132870
*112,900
*151852
*130,700
*174901
*93,000
*125413
*110,800
*149140
*129,200
*173545
Notes: 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. 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.
3. Make-up torque for 2 7/8 PAC connection is based on 87,500 psi stress and other factors listed in
note 1.
4. Make-up torque for H-90 connection is based on 56,200 psi stress and other factors listed in note 1.
69
11/18/2010 5:38:42 PM
Drill Collar Spiral Options
24”
3”
3”
30”
30”
Drill Collar
Drill Collar with
Zip Grooves
Drill Collar with
Hardband Grooves
and Zip Grooves
70
11/18/2010 5:38:42 PM
Hardbanding
71
11/18/2010 5:38:42 PM
Drill Collar Weight per Unit of Measure
lb/ft, kg/m
Drill Collar
OD (in)
2 7/8
3
3 1/8
3 1/4
3 1/2
3 3/4
4
4 1/8
4 1/4
4 1/2
4 3/4
5
5 1/4
5 1/2
5 3/4
6
6 1/4
6 1/2
6 3/4
7
7 1/4
7 1/2
7 3/4
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
1
19
28
21
31
22
33
26
39
30
45
35
52
40
60
43
64
46
68
51
76
1 1/4
18
27
20
30
22
33
24
36
29
43
33
49
39
58
41
61
44
65
50
74
Drill Collar ID (in)
1 1/2
16
24
18
27
20
30
22
33
27
40
32
48
37
55
39
58
42
62
48
71
54
80
61
91
68
101
75
112
82
122
90
134
98
146
107
159
116
172
125
186
134
199
144
214
154
229
1 3/4
2
35
52
37
55
40
60
46
68
52
77
59
88
65
97
73
108
80
119
88
131
96
143
105
156
114
170
123
183
132
196
142
211
152
226
32
48
35
52
38
56
43
64
50
74
56
83
63
94
70
104
78
116
85
126
94
140
102
152
111
165
120
179
130
193
139
207
150
223
72
11/18/2010 5:38:43 PM
Pound per foot
Kilogram per meter
2 1/4
2 1/2
2 13/16
29
43
32
48
35
52
41
61
47
70
53
79
60
89
67
100
75
112
83
124
91
135
99
147
108
161
117
174
127
189
137
204
147
218
44
65
50
74
57
85
64
95
72
107
79
118
88
131
96
143
105
156
114
170
124
184
133
198
144
214
60
89
67
100
75
111
83
123
91
135
100
149
110
163
119
177
129
192
139
207
3
3 1/4
3 1/2
3 3/4
4
64
95
72
107
80
119
89
132
98
146
107
159
116
172
126
187
136
202
72
107
80
119
89
132
98
146
108
161
117
174
128
190
93
138
103
153
113
168
123
183
84
125
93
138
102
152
112
166
60
89
68
101
76
113
85
126
93
138
103
153
112
166
122
181
132
196
Notes: Refer to API spec 7-1 Latest Edition for API standard drill collar dimensions. For special configurations
of drill collars, consult the manufacturer for reduction in weight.
73
11/18/2010 5:38:43 PM
Drill Collar Weight
Drill Collar OD
(in)
8
8 1/4
8 1/2
9
9 1/2
9 3/4
10
11
12
1
1 1/4
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
lbs/ft
kg/m
1 1/2
1 3/4
165
163
245
242
176
174
262
257
187
185
278
275
210
208
312
309
234
232
348
345
248
245
369
364
261
259
388
385
317
315
471
468
379
377
563
560
2
160
238
171
254
182
270
206
306
230
342
243
361
257
382
313
465
374
557
Notes:
1. Refer to API Spec 7-1 Latest Edition. Latest Edition for API standard drill collar dimensions.
30 ft (lb), 31 ft (kg)
Drill Collar OD
(in)
2 7/8
3
3 1/8
3 1/4
3 1/2
3 3/4
4
4 1/8
4 1/4
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
1
589
267
651
295
682
309
806
365
930
422
1,085
492
1,240
562
1,333
604
1,426
647
1 1/4
558
253
620
281
682
309
744
337
899
407
1,023
463
1,209
548
1,271
577
1,364
619
1 1/2
1 3/4
496
225
558
253
620
281
682
309
837
400
992
450
1,147
1,085
520
492
1,209
1,147
548
520
1,302
1,240
590
562
2
992
450
1,085
492
1,178
534
74
11/18/2010 5:38:43 PM
Pound per foot
Kilogram per meter
2 1/4
157
233
168
250
179
266
203
302
227
337
240
357
254
377
310
461
371
551
2 1/2
154
229
165
245
176
262
200
297
224
333
237
352
251
373
307
456
368
547
2 13/16
150
223
160
238
172
256
195
290
220
327
232
345
246
366
302
449
364
541
3
3 1/4
147
143
218
213
158
154
235
229
169
165
251
245
192
188
285
279
216
212
321
315
229
225
340
334
243
239
361
355
299
295
444
438
361
357
537
531
3 1/2
138
205
149
221
160
238
184
273
209
311
221
328
235
349
291
432
352
523
3 3/4
133
198
144
214
155
230
179
266
206
306
216
321
230
342
286
425
347
516
4
122
181
133
198
150
223
174
259
198
294
211
314
225
334
281
418
342
508
Notes (cont):
2. For special configurations of drill collars, consult manufacturer for reduction in weight.
Pound
Kilogram
2 1/4
2 1/2
2 13/16
3
3 1/4
3 1/2
3 3/4
4
899
407
992
450
1,085
492
Notes: Refer to API spec 7-1 Latest Edition for API standard drill collar dimensions. For special configurations
of drill collars, consult the manufacturer for reduction in weight.
75
11/18/2010 5:38:43 PM
Drill Collar Weight
31 ft (lb), 31 ft (kg)
Drill Collar OD
(in)
4 1/2
4 3/4
5
5 1/4
5 1/2
5 3/4
6
6 1/4
6 1/2
6 3/4
7
7 1/4
7 1/2
7 3/4
8
8 1/4
8 1/2
9
9 1/2
9 3/4
10
11
12
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
lbs
kg
1
1,581
717
1 1/4
1,550
703
1 1/2
1 3/4
1,488
1,426
675
646
1,674
1,612
759
731
1,891
1,829
857
829
2,108
2,015
956
913
2,325
2,263
1055
1026
2,542
2,480
1152
1125
2,790
2,728
1266
1237
3,038
2,976
1378
1350
3,317
3,255
1505
1476
3,596
3,534
1631
1603
3,875
3,813
1758
1730
4,154
4,092
1884
1856
4,464
4,402
2025
1997
4,774
4,712
2165
2137
5,115
5,053
2320
2292
5,456
5,394
2475
2447
5,797
5,735
2629
2601
6,510
6,448
2953
2925
7,254
7,192
3290
3262
7,688
7,595
3487
3445
8,091
8,029
3670
3642
9,827
9,765
4457
4429
11,749
11,687
5329
5301
2
1,333
604
1,550
703
1,736
787
1,953
885
2,170
984
2,418
1097
2,635
1195
2,914
1322
3,162
1434
3,441
1561
3,720
1687
4,030
1828
4,309
1955
4,650
2109
4,960
2250
5,301
2404
5,642
2559
6,386
2897
7,130
3234
7,533
3417
7,967
3614
9,703
4401
11,594
5259
Notes:
1. Refer to API Spec. 7-1 Latest Edition. Latest Edition for API standard drill collar dimensions.
2. For special configurations of drill collars, consult manufacturing for reduction in weight.
76
11/18/2010 5:38:44 PM
Pound
Kilogram
2 1/4
1,271
576
1,457
660
1,643
745
1,860
843
2,077
942
2,325
1055
2,573
1167
2,821
1280
3,069
1392
3,348
1519
3,627
1645
3,937
1786
4,247
1926
4,557
2067
4,867
2208
5,208
2362
5,549
2517
6,293
2854
7,037
3192
7,440
3375
7,874
3572
9,610
4359
11,501
5217
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
899
2,232
1012
2,449
1111
2,728
1237
2,976
1350
3,255
1476
3,534
1603
3,844
1744
4,123
1870
4,464
2024
4,774
2165
5,115
2320
5,456
2475
6,200
2812
6,944
3150
7,347
3333
7,781
3529
9,517
4317
11,408
5175
1,860
843
2,077
942
2,325
1055
2,573
1167
2,821
1280
3,100
1406
3,410
1547
3,689
1673
3,999
1814
4,309
1955
4,650
2109
4,960
2250
5,332
2419
6,045
2742
6,820
3093
7,192
3262
7,626
3459
9,362
4247
11,284
5118
1,984
899
2,232
1012
2,480
1125
2,759
1251
3,038
1378
3,317
1505
3,596
1631
3,906
1772
4,216
1912
4,557
2067
4,898
2222
5,239
2376
5,952
2700
6,696
3037
7,099
3220
7,533
3417
9,269
4204
11,191
5076
1,860
843
2,108
956
2,356
1069
2,635
1195
2,883
1308
3,193
1448
3,472
1575
3,782
1715
4,092
1856
4,433
2011
4,774
2165
5,115
2320
5,828
2644
6,572
2981
6,975
3164
7,409
3361
9,145
4148
11,067
5020
2,232
1012
2,480
1125
2,759
1252
3,038
1378
3,348
1519
3,627
1645
3,968
1800
4,278
1940
4,619
2095
4,960
2250
5,704
2587
6,479
2939
6,851
3108
7,285
3304
9,021
4092
10,912
4950
2,883
1308
3,193
1448
3,503
1589
3,813
1730
4,123
1870
4,464
2025
4,805
2180
5,549
2517
6,386
2897
6,696
3037
7,130
3234
8,866
4022
10,757
4879
2,604
1181
2,883
1308
3,162
1434
3,472
1575
3,782
1715
4,123
1870
4,650
2109
5,394
2447
6,138
2784
6,541
2967
6,975
3164
8,711
3951
10,602
4809
77
11/18/2010 5:38:44 PM
Drill Collar Bending Strength Ratios
1 1/2" ID
78
11/18/2010 5:38:44 PM
To obtain bending strength
ratio, measure OD & ID of drill
collar ar points shown in the
illustration.
1 3/4" ID
79
11/18/2010 5:38:44 PM
2" ID
80
11/18/2010 5:38:45 PM
collar at points shown in the
illustration.
2 1/4" ID
81
11/18/2010 5:38:45 PM
2 1/2" ID
82
11/18/2010 5:38:45 PM
illustration.
2 1/2" ID
83
11/18/2010 5:38:46 PM
2 13/16" ID
84
11/18/2010 5:38:46 PM
illustration.
2 13/16" ID
85
11/18/2010 5:38:46 PM
3" ID
86
11/18/2010 5:38:47 PM
illustration.
3" ID
87
11/18/2010 5:38:47 PM
3 1/4" ID
88
11/18/2010 5:38:47 PM
illustration.
3 1/4" ID
89
11/18/2010 5:38:48 PM
3 1/2" ID
90
11/18/2010 5:38:48 PM
illustration.
3 1/2" ID
91
11/18/2010 5:38:48 PM
API Interchangeable Connection Table
Connection Name
Numbered Connection (NC)
Size
26
31
38
Internal Flush (IF)
2 3/8
2 7/8
3 1/2
Slim Hole (SH)
2 7/8
3 1/2
4
Full Hole (FH)
40
46
50
4
4 1/2
4 1/2
4
Double Streamline (DSL)
3 1/2
Extra Hole (XH)
2 7/8
External Flush (EF)
4 1/2
3 1/2
5 1/2
4 1/2
5
4 1/2
92
11/18/2010 5:38:49 PM
Ideal Drill Collar Range
Hole
Size
(in)
Casing
Size To
Be Run
(in)
6 1/8
4 1/2
6 1/4
4 1/2
6 3/4
Ideal Collar Drill Range
Min.
(in)
API Drill Collar
Max.
(in)
Sizes Which Fall in the
Ideal Range (in)
3.875
4.750
4 1/8, 4 3/4
3.750
4.875
4 1/8, 4 3/4
4 1/2
3.250
5.125
3 1/2, 4 1/8, 4 3/4, 5
4 1/2
2.125
6.250
3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4
5 1/2
4.225
6.250
4 3/4, 5, 6, 6 1/4
5 1/2
3.725
6.750
4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4
6 5/8
6.405
6.750
6 1/2, 6 3/4
6 1/2, 6 3/4
7 7/8
8 3/8
6 5/8
6.280
6.750
7
6.8121
6.750
6 3/4
6 5/8
6.030
7.125
6 1/4, 6 1/2, 6 3/4, 7
7
6.562
7.125
6 3/4, 7
7
5.812
7.625
6, 6 1/4, 6 1/2, 7, 7 1/4
7 5/8
7.500
7.875
7 3/4
7
5.437
8.000
6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8
7 5/8
7.125
8.000
7 1/4, 7 3/4, 8
8 1/2
8 3/4
9 1/2
9 7/8
7 5/8
6.375
8.500
6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4
8 5/8
8.6252
8.500
8 1/4
8 5/8
8.250
8.875
8 1/4
9, 9 1/2, 9 3/4, 10
10 5/8
11
9 5/8
9.000
10.125
10 3/4
11.2502
10.125
10
10 3/4
9.750
11.250
9 3/4, 10, 11
12 1/4
13 3/4
14 3/4
11 3/4
10.750
12.000
11, 12
17 1/2
13 3/8
11.250
13.375
123
20
16
14.000
14.750
143
24
18 5/8
15.500
16.750
163
26
20
16.000
19.500
163
Notes:
1. 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.
2. Use a packed hole assembly instead of a pendulum.
3. Not API standard size drill collar.
93
11/18/2010 5:38:49 PM
Rig Tongs
Tong
Type
Jaw Sizes
(in)
Capacity
(ft-lbs)
Applicable API 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, 61/4,6 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
94
11/18/2010 5:38:49 PM
Subs and Kellys
Types of Subs
SUBS AND
KELLYS
95
11/18/2010 5:36:11 PM
Subs
General Notes on Subs
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.
4. Float bore not applicable for double-shouldered connections
Crossover Sub
96
11/18/2010 5:36:11 PM
Kelly Saver Subs
97
TAB 5 RSHandbook_SubsKellys.indd 97
11/18/2010 5:38:14 PM
Bit Sub
Lift Sub
98
11/18/2010 5:38:17 PM
Bit Box Float Bores
Box Up Float Bores
99
11/18/2010 5:38:17 PM
Kelly Weights – Pounds Per Foot
Drive Section Only
Square Kelly
1 1/4
3
26.4
3 1/2
1 1/2
1 3/4
24.6
22.4
35.6
33.5
2
2 1/4
31.0
28.1
4 1/4
2 1/2
2 3/4 2 13/16
47.9
44.7
41.2
2 1/2
2 3/4 2 13/16
36.5
33.0
32.1
61.0
60.0
3
3 1/4
3
3 1/4
57.1
52.9
40.3
Hexagon Kelly
3
3 1/2
1 1/4
1 1/2
22.3
20.5
30.1
4 1/4
1 3/4
2
2 1/4
27.9
25.4
22.5
39.7
5 1/4
100
11/18/2010 5:38:18 PM
40, 60
3 1/2
4 1/2 Reg.
5 3/4
7 3/4
6 5/8 Reg.
7 3/4
5 3/4
4 1/2 Reg.
6 5/8 Reg.
7 3/4
5 3/4
6 5/8 Reg.
4 1/2 Reg.
OD
(C)
Top Upset Joint
API Box
Thread
Left Hand
NC50(4 1/2IF)1
NC46(4 IF)1
NC38(3 1/2IF)
NC31(2 7/8IF)
6 3/8
6 1/4
4 3/4
4 1/8
OD
(D)
Botttom Upset
Right
Hand
Connections
Notes:
1. The lower end of 4 1/4 and 5 1/4 square kellys have two standard sizes and styles of connections.
2. All dimension in inches unless otherwise specified.
3. Short boreback standard in top box.
40, 60
40, 60
3
4 1/4
Available
Lengths
(ft)
(A)
Nominal
Size
2 13/16
2 1/4
1 3/4
Bore
(E)
5.500
4.437
3.875
4.25
3 1/2
3
Across
Flats
(G)
Drive Section
Across
Corners
(F)
1830
1300
1090
Approx.
wt. per
40 ft (lbs.)
Square Kelly
101
11/18/2010 5:38:18 PM
7 3/4
6 5/8 Reg.
7 3/4
5 3/4
6 5/8 Reg.
4 1/2 Reg.
5 3/4
7 3/4
6 5/8 Reg.
4 1/2 Reg.
5 3/4
7 3/4
6 5/8 Reg.
4 1/2 Reg.
OD
(C)
API Box
Thread
Left Hand
Top Upset Joint
NC50(4 1/2IF)*
NC46(4 IF)*
NC38(3 1/2IF)
NC31(2 7/8IF)
NC26 (2 3/8IF)
Right
Hand
Connections
6 3/8
6 1/4
4 3/4
4 1/8
3 3/8
OD
(D)
Botttom Upset
Notes:
1. The lower end of 4 1/4 and 5 1/4 square kellys have two standard sizes and styles of connections.
2. All dimension in inches unless otherwise specified.
3. Short boreback standard in top box.
40, 60
5 1/4
40, 60
3 1/2
40, 60
40, 60
3
4 1/4
Available
Lengths
(ft)
(A)
Nominal
Size
3 1/4
3
2 13/16
2 1/4
1 3/4
1 1/2
Bore
(E)
5.900
4.781
3.937
3.375
Across
Corners
(F)
5 1/4
4.25
3 1/2
3
Across
Flats
(G)
Drive Section
2560
1730
1290
1000
Approx.
wt. per
40 ft (lbs.)
Hexagonal Kelly
102
11/18/2010 5:38:18 PM
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.
Note: A worn out Drive Bushing can severely damage a new kelly.
103
11/18/2010 5:38:18 PM
Notes
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
104
11/18/2010 5:38:18 PM
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 (KWMOWM) ÷ (35.4-KWM)
Volume Increase in Bbls from adding Barite = Sacks Added ÷ 14.9
Volume Increase in Bbls from adding Barite = (Gel) = Sacks Added ÷ 8.75
Triplex Pump Output (bbls/stk @ 100%) = 0.000243 x Stroke Length x
(Liner Dia)2
Duplex Pump Outlet (bbl/stk @ 100%) = 0.000162 x Stroke x
[(2 x Liner Dia2) - Rod Dia2]
Annular Capacity (bbls/ft) = (ID2hole - OD2pipe) ÷ 1029
WELL CONTROL
105
11/18/2010 5:36:12 PM
Well Control
Capacity of DUPLEX Mud Pumps at 100% Efficiency
Liner Dia
Stroke Length (in)
(in)
12
14
16
4 1/2
0.074
0.082
–
18
–
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
106
API Standard Drill Pipe Capacity and Displacement
Size
OD
(in)
Size
ID
(in)
Nominal
Weight
(lb/ft)
Capacity
Displacement
(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
0.0096
5 1/2
4.67
24.7
0.0211
6 5/8
4.86
22.2
0.0229
0.0087
6 5/8
5.96
25.2
0.0346
0.0098
Size
OD
(in)
Size
ID
(in)
Weight
(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
Capacity
Displacement
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:
CAPACITY =
ID2
= bbls/ft
1029.4
DISPLACEMENT =
OD2 - ID2
= bbls/ft
1029.4
WEIGHT = DISPLACEMENT bbls/ft x 2747 lbs/bbl = lbs/ft
107
TAB 6 RSHandbook_WellControl.indd 107
11/18/2010 5:37:53 PM
108
11/18/2010 5:37:57 PM
6 1/2
6 1/4
6
5 3/4
5 1/2
5 1/4
5
4 3/4
4 1/2
4 1/4
4
OD
(in)
ID
Cap
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
1 1/2
0.0022
36.7
0.0133
42.4
0.0153
48.1
0.175
54.3
0.0197
60.8
0.0221
67.6
0.0246
74.8
0.0272
82.3
0.0299
90.1
0.0328
98.0
0.0356
107.0
0.0389
1 3/4
0.0030
34.5
0.0125
40.0
0.0145
45.9
0.0167
52.1
0.0189
58.6
0.0213
65.4
0.0238
72.6
0.0264
80.1
0.0291
87.9
0.0320
95.8
0.0349
104.8
0.0381
2
0.0039
32.0
0.0116
37.5
0.0136
43.4
0.0158
49.6
0.0181
56.1
0.0204
62.9
0.0229
70.1
0.0255
77.6
0.0282
85.4
0.0311
93.3
0.0339
102.3
0.0372
2 1/4
0.0049
29.2
0.106
34.7
0.0126
40.6
0.0148
46.8
0.0170
53.3
0.0194
60.1
0.0219
67.3
0.0245
74.8
0.0272
82.6
0.0301
90.5
0.0329
99.5
0.0362
2 1/2
0.0061
43.6
0.0159
50.1
0.0182
56.9
0.0207
64.1
0.0233
71.6
0.0261
79.4
0.0289
87.3
0.0318
96.3
0.0350
Drill Collar Capacity and Displacement (bbls/ft)
2 3/4
0.0073
53.4
0.0194
60.6
0.0221
68.1
0.0248
75.9
0.0276
83.8
0.0305
92.8
0.0338
3
0.0087
56.8
0.0207
64.3
0.0234
72.1
0.0262
80.0
0.0291
89.0
0.0324
3 1/4
0.0103
67.9
0.0247
75.8
0.0276
84.8
0.0308
3 1/2
0.0119
63.4
0.0231
71.3
0.0259
80.3
0.0292
3 3/4
0.0137
-
4
0.0155
-
4 1/4
0.0175
-
109
11/18/2010 5:37:57 PM
10
9
8 3/4
8 1/2
8 1/4
8
7 3/4
7 1/2
7 1/4
7
6 3/4
OD
(in)
ID
Cap
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
lb/ft
Disp.
1 1/2
0.0022
116.0
0.0422
125.0
0.0455
134.0
0.0487
144.0
0.0524
154.0
0.0560
165.0
0.0600
176.0
0.0640
187.0
0.0680
199.0
0.0724
210.2
0.0765
260.9
0.0950
1 3/4
0.0030
113.8
0.0414
122.8
0.0447
131.8
0.0479
141.8
0.0516
151.8
0.0552
162.8
0.0592
173.8
0.0632
184.8
0.0672
196.8
0.0716
208.0
0.0757
258.8
0.0942
2
0.0039
111.3
0.0405
120.3
0.0438
129.3
0.0470
139.3
0.0507
149.3
0.0543
160.3
0.0583
171.3
0.0623
182.3
0.0663
194.3
0.0707
205.6
0.0748
256.3
0.0933
2 1/4
0.0049
108.5
0.0395
117.5
0.0427
126.5
0.0460
136.5
0.0497
146.5
0.0533
157.5
0.0573
168.5
0.0613
179.5
0.0653
191.5
0.0697
202.7
0.0738
253.4
0.0923
2 1/2
0.0061
105.3
0.0383
114.3
0.0416
123.3
0.0449
133.3
0.0485
143.3
0.0521
154.3
0.0561
165.3
0.0601
176.3
0.0641
188.3
0.0685
199.6
0.0726
250.3
0.0911
2 3/4
0.0073
101.8
0.0370
110.8
0.0403
119.8
0.0436
129.8
0.0472
139.8
0.0509
150.8
0.0549
161.8
0.0589
172.8
0.0629
184.8
0.0672
196.0
0.0714
246.8
0.0898
Drill Collar Capacity and Displacement (bbls/ft) (Cont.)
3
0.0087
98.0
0.0356
107.0
0.0389
116.0
0.0422
126.0
0.0458
136.0
0.0495
147.0
0.0535
158.0
0.0575
169.0
0.0615
181.0
0.0658
192.2
0.0700
242.9
0.0884
3 1/4
0.0103
93.8
0.0341
102.8
0.0374
111.8
0.0407
121.8
0.0443
131.8
0.0479
142.8
0.0520
153.8
0.0560
164.8
0.0600
176.8
0.0643
188.0
0.0685
238.8
0.0869
3 1/2
0.0119
89.3
0.0325
98.3
0.0358
107.3
0.0390
117.3
0.0427
127.3
0.0463
138.3
0.0503
149.3
0.0543
160.3
0.0583
172.3
0.0697
183.5
0.0668
234.3
0.0853
3 3/4
0.0137
93.4
0.0340
102.4
0.0372
112.4
0.0409
122.4
0.0445
133.4
0.0485
144.4
0.0525
155.4
0.0565
167.4
0.0609
178.7
0.0651
229.4
0.0835
4
0.0155
88.3
0.0321
97.3
0.0354
107.3
0.0390
117.3
0.0427
123.3
0.0467
139.3
0.0507
150.3
0.0547
162.3
0.0590
173.5
0.0632
224.2
0.0816
4 1/4
0.0175
122.8
0.0447
133.8
0.0487
144.8
0.0527
156.8
0.0570
168.0
0.0612
218.7
0.0796
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
0.856
9.4
70.32
1.12
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
110
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Mud Density
(lb/gal)
(lb/cu ft)
(g/cc)
Buoyancy
Factor (Kb)
0.786
14.0
104.73
1.68
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
0.746
16.6
124.18
1.99
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
111
11/18/2010 5:37:58 PM
Formulas Used In Well Control
and Drilling Operations
Calculating Pressure, psi and Pressure Gradients, psi/ft
1. Determine pressure gradient, psi/ft
(Mud Weight, ppg) x (0.052) = psi/ft
2. Determine hydrostatic pressure, psi (H.P.)
(Mud Wt., ppg) x (0.052) x (T.V.D., ft) = psi
3. Maximum allowable shut in casing pressure
Maximum
Allowable Mud Wt., ppg
Mud Wt.
in use
ppg
x (0.052) x (TVD, ft.) = psi
112
11/18/2010 5:37:58 PM
Converting Pressures, psi into mud weight, ppg
Anytime a pressure is to be converted to mud weight use the following formulas
• Mud Weight, ppg (MW)
(Pressure, psi) ÷ (0.052) ÷ (TVD, ft) = Mud Weight, ppg
• Kill Weight Mud, ppg (KWM)
(SIDPP, psi) ÷ (0.052) ÷ (TVD, ft) + (O.M.W.) = Kill Wt., ppg
• Equivalent Mud Weight, ppg (EMW)
(pressure, psi) ÷ (0.052) ÷ (TVD, ft) = EMW, ppg
• Equivalent Circulating Density, ppg (ECD)
Annular
Pressure
Loss, psi
÷ (0.052) ÷ (TVD, ft) + (OMW) = ECD, ppg
• Maximum Allowable Mud Weight, ppg (MAMW)
Leak-Off
Pressure
Loss, psi
÷ (0.052) ÷ (TVD, ft) +
Test
Mud
Weight
= MAMW, ppg
• Converting Pressure Gradient, psi/ft to Mud Wt, ppg
(Pressure Gradient, PSI/ft.) ÷ (0.052) = Mud Wt, ppg
OMW - original mud weight
SIDPP - shut in drill pipe pressure
TVD - true vertical depth
113
11/18/2010 5:35:05 PM
Downhole Solutions
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© 2010 National Oilwell Varco
D392002466-MKT-001 Rev. 02
11/18/2010 5:35:05 PM

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