mkt-001 rev 02 rotary shoulder handbook rs
TRANSCRIPT
ROTARY SHOULDER HANDBOOK
D392002466-MKT-001 Rev 02 Handbook Cover.indd 1D392002466-MKT-001 Rev 02 Handbook Cover.indd 1 1/11/2011 10:52:06 AM1/11/2011 10:52:06 AM
© 2011 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.
ContentsSection 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
D392002466-MKT-001 Rev 02 Handbook Cover.indd 2D392002466-MKT-001 Rev 02 Handbook Cover.indd 2 1/11/2011 10:52:36 AM1/11/2011 10:52:36 AM
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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2
New Tool Joints
Drill PipeSize (in)
ConnectionBox OD1
(in)
Pin ID
(in)
Make-up Torque2,3
(ft-lb)
2 3/8
NC26 (IF) 3 3/8 1 3/4 3,900
OHLW 3 1/8 2 2,600
OHSW 3 1/4 1 3/4 3,700
SLH-90 3 1/4 2 2,700
WO 3 3/8 2 2,400
PAC 2 7/8 1 3/8 2,600
2 7/8
2 7/8” SH (NC26) 3 3/8 1 3/4 3,900
OHLW 3 3/4 2 7/16 3,100
OHSW 3 7/8 2 5/32 4,800
SLH-90 3 7/8 2 7/16 4,000
SLH-90 3 7/8 2 5/32 5,900
PAC 3 1/8 1 1/2 3,200
WO 4 1/8 2 7/16 3,900
X.H. 4 1/4 1 7/8 7,000
NC31 (IF) 4 1/8 2 1/8 6,400
NC31 (IF) 4 1/8 2 7,100
NC31 (IF) 4 3/8 1 5/8 9,000
3 1/2
3 1/2 SH (NC31) 4 1/8 2 1/8 6,400
SLH-90 4 5/8 3 6,500
SLH-90 4 5/8 2 11/16 9,500
OHLW 4 3/4 3 6,500
OHSW 4 3/4 2 11/16 9,300
NC38 (WO) 4 3/4 3 6,800
NC38 (IF) 4 3/4 2 11/16 9,700
NC38 (IF) 5 2 9/16 10,700
NC38 (IF) 5 2 7/16 11,700
NC38 (IF) 5 2 1/8 14,000
NC40 (4” FH) 5 1/4 2 9/16 14,600
NC40 (4” FH) 5 3/8 2 7/16 15,600
NC40 (4” FH) 5 1/2 2 1/4 17,100
4
SH (3 1/2”XH) 4 5/8 2 9/16 8,100
OHLW 5 1/4 3 15/32 11,900
OHSW 5 1/2 3 1/4 14,700
NC40 (4” FH) 5 1/4 2 13/16 12,400
NC40 (4” FH) 5 1/4 2 11/16 13,500
NC40 (4” FH) 5 1/2 2 7/16 15,600
NC40 (4” FH) 5 1/2 2 7/16 15,600
NC46 (WO) 5 3/4 3 7/16 15,200
NC46 (IF) 6 3 1/4 17,600
NC46 (IF) 6 3 20,500
NC46 (IF) 6 3 20,500
NC46 (IF) 6 3 1/4 17,600
NC46 (IF) 6 3 20,500
NC46 (IF) 6 2 5/8 24,400
NC46 (IF) 6 2 7/8 21,900
Torque Chart-Drill Pipe Tool Joint
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.
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3
Used Tool JointsPremium Class 2
Box OD1 (in)
Make-UpTorque2,3
(ft-lb)
Box OD1 (in)
Make-UpTorque2,3
(ft-lb)
3 1/4 3,000 3 3/16 2,500
3 1/16 2,300 3 1/32 2,100
3 1,800 2 31/32 1,600
2 31/32 2,000 3 31/32 2,000
3 1/16 2,000 3 1,500
2 25/32 2,500 2 23/32 2,100
3 3/8 3,900 3 5/16 3,600
3 1/2 3,100 3 7/16 2,700
3 19/32 4,300 3 17/32 3,600
3 17/32 3,800 3 17/32 3,800
3 19/32 4,500 3 17/32 3,800
3 1/8 3,500 3 1/16 3,500
3 5/8 3,200 3 9/16 2,500
3 23/32 4,400 3 21/32 3,700
3 11/16 3,200 3 21/32 2,800
3 29/32 5,700 3 13/16 4,600
4 1/16 7,700 3 31/32 6,500
4 6,400 3 29/32 5,700
4 3/16 5,500 4 1/8 4,500
4 3/8 8,800 4 9/32 7,100
4 9/32 5,500 4 7/32 4,600
4 3/8 7,000 4 5/16 6,000
4 3/8 5,300 4 11/32 4,800
4 3/8 5,300 4 11/32 4,800
4 19/32 8,800 4 1/2 7,300
4 21/32 9,900 4 9/16 8,300
4 23/32 10,900 4 5/8 9,300
4 15/32 11,400 4 13/32 9,000
5 12,600 4 7/8 10,200
5 3/32 14,400 4 15/16 11,400
4 7/16 8,800 4 11/32 7,400
4 31/32 7,500 4 29/32 6,200
5 1/32 8,800 4 31/32 7,500
4 13/16 9,000 4 23/32 7,300
4 15/16 11,400 4 13/16 9,000
5 12,600 4 7/8 10,200
5 12,600 4 7/8 10,200
5 7/32 7,900 5 5/32 6,500
5 5/32 10,000 5 7/32 7,900
5 7/16 12,800 5 5/16 10,000
5 15/32 13,600 5 3/8 11,400
5 9/32 9,200 5 3/16 7,200
5 9/16 15,800 5 7/16 12,800
5 5/8 17,300 5 1/2 14,300
5 5/8 17,300 5 1/2 14,300
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.
TAB 1 RSHandbook_Drill Pipe.indd 3TAB 1 RSHandbook_Drill Pipe.indd 3 11/18/2010 5:36:37 PM11/18/2010 5:36:37 PM
4
Torque Chart-Drill Pipe Tool Joint (cont.)
New Tool Joints
Drill PipeSize(in)
ConnectionBox OD1
(in)
Pin ID
(in)
Make-upTorque2,3
(ft-lb)
4 1/2
OHSW 5 7/8 3 3/4 14,600
FH 6 3 17,600
FH 6 2 3/4 20,100
FH 6 2 1/2 22,300
NC46 (XH) 6 1/4 3 1/4 17,600
NC46 (XH) 6 1/4 3 20,500
NC46 (XH) 6 1/4 2 3/4 23,200
NC46 (XH) 6 1/4 2 1/2 25,600
NC50 (IF) 6 3/8 3 3/4 19,800
NC50 (IF) 6 3/8 3 3/4 19,800
NC50 (IF) 6 3/8 3 5/8 21,600
NC50 (IF) 6 3/8 3 1/2 23,400
NC50 (IF) 6 3/8 2 7/8 30,300
5
NC50 (XH) 6 3/8 33/4 19,800
NC50 (XH) 6 3/8 3 1/2 23,400
NC50 (XH) 6 1/2 3 1/4 26,800
NC50 (XH) 6 1/2 3 30,000
NC50 (XH) 6 5/8 2 3/4 32,900
5 1/2” FH 7 3 1/2 37,400
5 1/2” FH 7 1/4 3 1/2 37,400
5 1/2” FH 7 1/4 3 1/4 41,200
5 1/2
FH 7 4 29,200
FH 7 4 29,200
FH 7 3 3/4 33,400
FH 7 1/4 3 1/2 37,400
FH 7 1/4 3 1/2 37,400
FH 7 1/4 3 1/2 37,400
FH 7 1/2 3 44,600
FH 7 1/2 3 44,600
6 5/8
FH 8 5 38,400
FH 8 5 38,400
FH 8 5 38,400
FH 8 1/4 4 3/4 44,600
FH 8 1/4 4 3/4 44,600
FH 8 1/4 4 3/4 44,600
FH 8 1/2 4 1/4 56,100
FH 8 1/2 4 1/4 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.
TAB 1 RSHandbook_Drill Pipe.indd 4TAB 1 RSHandbook_Drill Pipe.indd 4 11/18/2010 5:36:42 PM11/18/2010 5:36:42 PM
5
Used Tool JointsPremium Class 2
BoxOD1
(in)
Make-UpTorque2,3
(ft-lb)
BoxOD1
(in)
Make-upTorque2,3
(ft-lb)
5 15/32 12,300 5 3/8 10,000
5 3/8 12,100 5 9/32 10,100
5 9/16 16,400 5 7/16 13,500
5 5/8 17,800 5 15/32 14,200
5 13/32 12,100 5 5/16 9,900
5 19/32 16,500 5 15/32 13,500
5 25/32 21,200 5 5/8 17,300
5 23/32 19,600 5 9/16 15,800
5 29/32 16,600 5 25/32 13,200
5 23/32 11,600 5 21/32 10,000
5 13/16 14,100 5 23/32 11,600
5 15/16 17,500 5 27/32 14,900
6 7/32 25,500 6 1/16 21,000
5 7/8 15,800 5 25/32 13,300
6 1/32 20,200 5 29/32 16,700
6 3/32 21,900 5 31/32 18,400
6 3/16 24,700 6 1/32 22,000
6 5/16 28,400 6 3/16 24,600
6 21/32 25,500 6 1/2 20,200
6 23/32 27,700 6 9/16 22,300
6 15/16 35,500 6 3/4 28,800
6 17/32 21,300 6 7/16 18,200
6 9/16 22,300 6 15/32 19,200
6 5/8 24,500 6 1/2 20,300
6 23/32 27,650 6 19/32 23,350
6 25/32 29,900 6 5/8 24,500
6 25/32 29,900 6 11/16 26,560
7 1/32 39,000 6 27/32 32,100
7 1/32 39,000 6 7/8 33,200
7 7/16 26,800 7 3/8 24,100
7 1/2 29,500 7 13/32 25,500
7 5/8 35,100 7 1/2 29,500
7 11/16 38,000 7 9/16 32,300
7 11/16 38,000 7 19/32 33,700
7 3/4 40,900 7 21/32 36,500
7 29/32 48,200 7 25/32 42,300
8 52,700 7 27/32 45,200
TAB 1 RSHandbook_Drill Pipe.indd 5TAB 1 RSHandbook_Drill Pipe.indd 5 11/18/2010 5:36:42 PM11/18/2010 5:36:42 PM
6
Performance Properties of Seamless Drill PipeNe
w Dr
ill P
ipe D
imen
siona
l, To
rsio
nal a
nd Te
nsile
Dat
a
Size OD (in
)
Nom
inal
Wei
ght
(lb/f
t)
Wal
lTh
ick-
ness
(in)
ID (in)
Cros
s Se
ctio
nal
Area
of
Pip
e(sq
in)
Pola
rSe
ctio
nal
Mod
ulus
Z(cu
in)
Tors
iona
l Yie
ld St
reng
th (f
t-lb)
Tens
ile Yi
eld S
treng
th (l
b)
E75
X95
G105
S135
E75
X95
G105
S135
2 3/
84.
856.
650.
190
0.28
01.
995
1.81
51.
3042
1.84
291.
320
1.73
44,
760
6,24
06,
020
7,90
06,
060
8,74
0– –
97,8
2013
8,22
012
3,90
017
5,08
013
6,94
019
3,50
017
6,07
024
8,79
0
2 7/
86.
8510
.40
0.21
70.
362
2.44
12.
151
1.81
202.
8579
2.24
23.
204
8,07
011
,530
10,2
2014
,610
11,3
0016
,150
–20
,760
135,
900
214,
340
172,
140
271,
500
190,
260
300,
080
244,
620
385,
820
3 1/
29.
5013
.30
15.5
0
0.25
40.
368
0.44
9
2.99
22.
764
2.60
2
2.59
023.
6209
4.30
37
3.92
25.
144
5.84
6
14,1
2018
,520
21,0
50
17,8
9023
,460
26,6
60
19,7
7025
,930
29,4
70
25,4
2033
,330
37,8
90
194,
260
271,
570
322,
780
246,
070
343,
990
408,
850
271,
970
380,
190
451,
890
349,
680
488,
820
581,
000
411
.85
14.0
015
.70
0.26
20.
330
0.38
0
3.47
63.
340
3.24
0
3.07
673.
8048
4.32
16
5.40
06.
458
7.15
6
19,4
4023
,250
25,7
60
24,6
2029
,450
32,6
30
27,2
2032
,550
36,0
70
34,9
9041
,840
46,3
80
230,
750
285,
360
324,
150
292,
290
361,
460
410,
590
323,
050
399,
500
453,
810
415,
360
513,
650
583,
420
4 1/
213
.75
16.6
020
.00
0.27
10.
337
0.43
0
3.95
83.
826
3.64
0
3.60
044.
4074
5.49
81
7.18
48.
542
10.2
32
25,8
6030
,750
36,8
40
32,7
6038
,950
46,6
60
36,2
1043
,050
51,5
70
46,5
5055
,350
66,3
00
270,
030
330,
560
412,
360
342,
040
418,
700
522,
320
378,
050
462,
780
577,
300
486,
060
595,
000
742,
240
519
.50
25.6
00.
362
0.50
04.
276
4.00
05.
2746
7.06
8611
.416
14.4
9041
,090
52,1
6052
,050
66,0
7057
,530
73,0
3073
,970
93,9
0039
5,60
053
0,14
050
1,09
067
1,52
055
3,83
074
2,20
071
2,07
095
4,26
0
5 1/
221
.90
24.7
00.
361
0.41
54.
778
4.67
05.
8282
6.62
9614
.062
15.6
8850
,620
56,4
7064
,120
71,5
3070
,870
79,0
6091
,120
101,
650
437,
120
497,
220
553,
680
629,
810
611,
960
696,
110
786,
810
895,
000
5 7/
8 23
.40
26.3
0 0
.361
0.
415
5.15
3 5.
045
6.25
357.
1185
16.2
5118
.165
58,6
0065
,500
74,2
00
83,0
0082
,000
91
,700
105,
500
117,
900
469,
000
533,
900
594,
100
676,
300
656,
600
747,
400
844,
200
961,
000
6 5/
825
.20
27.7
00.
330
0.36
25.
965
5.90
16.
5262
7.12
2619
.572
21.1
5670
,550
89,3
6098
,770
106,
800
127,
044
137,
300
489,
460
534,
200
619,
990
676,
700
685,
250
747,
900
881,
044
961,
600
76,3
0096
,600
TAB 1 RSHandbook_Drill Pipe.indd 6TAB 1 RSHandbook_Drill Pipe.indd 6 11/18/2010 5:36:42 PM11/18/2010 5:36:42 PM
7
New Drill Pipe Collapse and Internal Pressure Data
Size OD (in
)
Nom
inal
Wei
ght
(lb)
Mat
eria
l Gra
de
Colla
pse P
ress
ure,
(psi)
Inte
rnal
Pre
ssur
e, (p
si)
E75
X95
G105
S135
E75
X95
G105
S135
2 3/
84.
856.
6511
,040
15,6
0013
,980
19,7
6015
,460
21,8
4019
,070
28,0
8010
,500
15,4
7013
,300
19,6
0014
,700
21,6
6018
,900
27,8
50
2 7/
86.
8510
.40
10,4
7016
,510
12,9
3020
,910
14,0
1023
,110
17,0
6029
,720
9,91
016
,530
12,5
5020
,930
13,8
7023
,140
17,8
3029
,750
3 1/
29.
5013
.30
15.5
0
10,0
4014
,110
16,7
70
12,0
6017
,880
21,2
50
13,0
5019
,760
23,4
80
15,7
8025
,400
30,1
90
9,52
013
,800
16,8
40
12,0
7017
,480
21,3
30
13,3
4019
,320
23,5
70
17,1
5024
,840
30,3
10
411
.85
14.0
015
.70
8,41
011
,350
12,9
00
9,96
014
,380
16,3
40
10,7
0015
,900
18,0
50
12,6
5020
,170
23,2
10
8,60
010
,830
12,4
70
10,8
9013
,720
15,7
90
12,0
4015
,160
17,4
60
15,4
8019
,490
22,4
40
4 1/
213
.75
16.6
020
.00
7,20
010
,390
12,9
60
8,40
012
,750
16,4
20
8,95
013
,820
18,1
50
10,3
1016
,800
23,3
30
7,90
09,
830
12,5
40
10,0
1012
,450
15,8
90
11,0
7013
,760
17,5
60
14,2
3017
,690
22,5
80
519
.50
25.6
010
,000
13,5
0012
,010
17,1
0012
,990
18,9
0015
,700
24,3
009,
500
13,1
2012
,040
16,6
2013
,300
18,3
8017
,110
23,6
20
5 1/
221
.90
24.7
08,
440
10,4
6010
,000
12,9
2010
,740
14,0
0012
,710
17,0
508,
610
9,90
010
,910
12,5
4012
,060
13,8
6015
,510
17,8
30
5 7/
823
.40
26.3
07,
450
9,56
0 8
,770
11,5
009,
360
12,4
1010
,820
14,8
908,
060
9,27
010
,220
11,7
4011
,290
12,9
8014
,520
16,6
90
6 5/
825
.20
27.7
04,
810
5,89
05,
310
6,75
05,
490
7,10
06,
040
7,81
06,
540
7,17
08,
280
9,08
09,
150
10,0
4011
,770
12,9
10
TAB 1 RSHandbook_Drill Pipe.indd 7TAB 1 RSHandbook_Drill Pipe.indd 7 11/18/2010 5:36:42 PM11/18/2010 5:36:42 PM
8
Tool Joint Bevel Diameters
Type Size (in) OD (in) Bev. Dia. (in)
Internal Flush
&Numbered
Connections
2 3/8 & NC26 3 3/8 3 17/64
2 7/8 & NC31 4 1/8 3 61/64
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
Full Hole&
NumberedConnections
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
Xtra Hole &Numbered
Connections
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
H-904 5 1/2 5 17/64
4 1/2 6 5 23/32
SlimlineH-90
2 3/8 3 1/4 3 1/8
2 7/8 3 7/8 3 23/32
3 1/2 4 5/8 4 7/16
Slimhole &
NumberedConnections
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
TAB 1 RSHandbook_Drill Pipe.indd 8TAB 1 RSHandbook_Drill Pipe.indd 8 11/18/2010 5:36:43 PM11/18/2010 5:36:43 PM
9
Decimal and Millimeter Equivalents
1 mm = 0.03937 inch0.001 inch = 0.0254 mm
Fraction Decimal mm
1/64 0.015625 0.397
1/32 0.03125 0.794
3/64 0.046875 1.191
1/16 0.0625 1.588
5/64 0.078125 1.984
3/32 0.09375 2.381
7/64 0.109375 2.778
1/8 0.1250 3.175
9/64 0.140625 3.572
5/32 0.15625 3.969
11/64 0.171875 4.366
3/16 0.1875 4.763
13/64 0.203125 5.159
7/32 0.21875 5.556
15/64 0.234375 5.953
1/4 0.2500 6.350
17/64 0.265625 6.747
9/32 0.28125 7.144
19/64 0.296875 7.541
5/16 0.3125 7.938
21/64 0.328125 8.334
11/32 0.34375 8.731
23/64 0.359375 9.128
3/8 0.3750 9.525
25/64 0.390625 9.922
13/32 0.40625 10.319
27/64 0.421875 10.716
7/16 0.4375 11.113
29/64 0.453125 11.509
15/32 0.46875 11.906
31/64 0.484375 12.303
1/2 0.5000 12.700
Fraction Decimal mm
33/64 0.515625 13.097
17/32 0.53125 13.494
35/64 0.546875 13.891
9/16 0.5625 14.288
37/64 0.578125 14.684
19/32 0.59375 15.081
39/64 0.609375 15.478
5/8 0.6250 15.875
41/64 0.640625 16.272
21/32 0.65625 16.669
43/64 0.671875 17.066
11/16 0.6875 17.463
45/64 0.703125 17.859
23/32 0.71875 18.256
47/64 0.734375 18.653
3/4 0.7500 19.050
49/64 0.765625 19.447
25/32 0.78125 19.844
51/64 0.796875 20.241
13/16 0.8125 20.638
53/64 0.828125 21.034
27/32 0.84375 21.431
55/64 0.859375 21.828
7/8 0.8750 22.225
57/64 0.890625 22.622
29/32 0.90625 23.019
59/64 0.921875 23.416
15/16 0.9375 23.813
61/64 0.953125 24.209
31/32 0.96875 24.606
63/64 0.984375 25.003
1 1.000 25.400
TAB 1 RSHandbook_Drill Pipe.indd 9TAB 1 RSHandbook_Drill Pipe.indd 9 11/18/2010 5:36:43 PM11/18/2010 5:36:43 PM
10
Conversion of Customary Units to SI/Metric Units
BasicUnit
CustomaryUnits
(Abbreviation)
SI/MetricUnits
(Abbreviation)
ConversionCustomary to
SI/MetricMultiply by
Length in mm 25.4
Area sq in mm2 645.16
Volume, capacity
cu ft
U.K. gal
U.S. gal
m3
L
L
0.028317
4.546092
3.785412
Plane angle deg (0) rad 0.017453
Time min S 60
Mass lbm kg 0.453592
Temperature (traditional) °F °C(°F-32)
1.8
Pressure
lbf/in2(psi)
N/m2
at (kp/cm2)
bar
bar
Pa
bar
Pa
0.068947
1.
1.0197
105
Density (liquids)
lbm/U.S. gal
lbm/U.K. gal
lbm/ft
kg/m3
kg/m3
kg/m3
119.8264
99.77633
16.01846
Density (solids) lbm/ft3 kg/m3 16.01846
Throughput (mass basis) lbm/hr kg/h 0.453592
Throughput (volume basis)
bbl/D
ft3/D
U.K. gal/min
U.S. gal/min
m3/h
m3/h
L/min
L/min
0.006624
0.001179
4.546092
3.785412
Flow rate (volume basis)
U.K. gal/min
U.S. gal/min
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.
Power
hydraulic horse
power-hhp
hp (electric)
Btu/hr
kW
kW
W
0.746043
0.746
0.293071
Fuel consumptionmile/U.S. gal
mile/U.K. gal
km/L
km/L
0.425144
0.354066
Velocity (linear) speedft/min
in/s
m/s
mm/s
0.005080
25.4
Rotational frequencyrev/s
rev/min
rev/s
rev/s
1.0
0.016666
Weight/length lb/ft kg/m 1.488164
Forcelbf
kg-m/sec2
N
N
4.448222
1.
Bending moment torque lbf-ft Nm 1.355818
Section modulus cu in mm3 2831685
Stress kgf/mm2
lbf/in2 (psi)
N/mm2
N/mm2
9.806650
0.006895
TAB 1 RSHandbook_Drill Pipe.indd 10TAB 1 RSHandbook_Drill Pipe.indd 10 11/18/2010 5:36:43 PM11/18/2010 5:36:43 PM
DO
UBLE-
SHO
ULD
EREDCO
NN
ECTION
S
Pin Base
Pin base extends in
spring-like manner
when joint is bucked
up to recommended
make-up torque.
Secondary Shoulder
When joint is hand
tight, secondary
shoulders do not
contact. When joint
is bucked up to
recommended
make-up torque,
they do contact.
Primary Shoulder
Provides seal and
preload just as on
conventional tool
joint.
Box Counterbore Section
Box counterbore
section compresses
in spring-like
manner when joint
is bucked up to
recommended
make-up torque.
Pin Nose
Drill Pipe with Double-Shouldered Connections
Box
Weld
Pipe
PinExternal Upset
Tool Joint
Elevator ShoulderInternal Upset
Internal Coating
Hardbanding
11
GP-7033 Handbook_Tabs.indd 3GP-7033 Handbook_Tabs.indd 3 11/18/2010 5:36:06 PM11/18/2010 5:36:06 PM
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 con-
nections 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.
• 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.
XT
HT
Types of Grant Prideco Double-Shouldered Connections
12
GP-7033 Handbook_Tabs.indd 4GP-7033 Handbook_Tabs.indd 4 11/18/2010 5:36:06 PM11/18/2010 5:36:06 PM
13
• 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.
Starting Thread
Starting Thread 2
Starting Thread 1
XT®57≈ 13 revolutions
TurboTorque® 585≈ 4 revolutions
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.
TAB 2 RSHandbook_DSC.indd Sec1:13TAB 2 RSHandbook_DSC.indd Sec1:13 12/20/2010 9:41:27 AM12/20/2010 9:41:27 AM
14
TurboTorque® Tool Joint Make-up Torque Chart
Note: 1. Applies to drill pipe and heavy weight drill pipe tool joints. See page 13.
TypeConnection
BoxOD(in)
PinID
(in)
MinimumMUT
(ft-lb)
RecommendedMUT
(ft-lb)
Turbo-MUT™ (ft-lb)1
TurboTorque 3804 3/4
4 13/162 11/16
2 1/216,80019,900
20,20023,900
21,90025,900
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 4856
6 1/83 9/163 1/4
31,50039,700
37,80047,600
40,90051,600
TurboTorque 500 6 1/4 3 1/2 38,900 46,600 50,500
TurboTorque 5256 1/26 5/8
3 7/83 9/16
38,20048,000
45,80057,600
49,60062,400
TurboTorque 550 6 5/8 4 1/4 39,100 46,900 50,900
TurboTorque 5857
7 1/84 1/2
4 5/1647,80055,500
57,30066,600
62,10072,200
TurboTorque 690 8 1/4 5 1/2 63,100 75,800 82,100
TAB 2 RSHandbook_DSC.indd Sec1:14TAB 2 RSHandbook_DSC.indd Sec1:14 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
15
TurboTorque-M™ Tool Joint Make-up Torque Chart
TypeConnection
BoxOD(in)
PinID
(in)
MinimumMUT
(ft-lb)
RecommendedMUT
(ft-lb)
Turbo-MUT™ (ft-lb)1
TurboTorque-M 3804 3/4
4 13/162 11/16
2 1/214,80017,900
17,70021,400
19,20023,200
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 4856
6 1/83 9/163 1/4
28,20036,500
33,90043,800
36,70047,400
TurboTorque-M 500 6 1/4 3 1/2 35,400 42,500 46,000
TurboTorque-M 5256 1/26 5/8
3 7/83 9/16
34,40044,200
41,20053,100
44,70057,500
TurboTorque-M 550 6 5/8 4 1/4 34,900 41,800 45,300
TurboTorque-M 5857
7 1/84 1/2
4 5/1643,00050,800
51,60060,900
55,90066,000
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.
TAB 2 RSHandbook_DSC.indd Sec1:15TAB 2 RSHandbook_DSC.indd Sec1:15 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
16
XT® Tool Joint Make-up Torque Chart
Note: Applies to drill pipe and heavy weight drill pipe tool joints.
Type Connection
Box OD(in)
Pin ID (in)
XT® Recommended MUT
(ft-lb)
XT24 3 1/8 1 1/2 5,700
XT26
3 1/2
3 1/2
3 1/2
1 3/4
1 1/2
1 1/4
6,900
8,900
9,900
XT29 3 3/4 2 9,000
XT31
4 1/8
4 1/8
4
4
2
1 7/8
2
2 1/8
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
4 7/8
5
5
5
5
2 9/16
2 11/16
2 3/4
2 13/16
2 7/8
2 13/16
2 11/16
2 9/16
22,200
21,200
20,700
19,800
18,600
19,800
22,200
24,500
XT405 1/4
5 1/4
3
2 13/16
22,400
26,400
XT435 3/4
5 3/8
2 3/4
3
34,000
28,300
XT46 6 1/4 3 1/4 42,100
XT50
6 5/8
6 5/8
6 1/2
6 3/8
6 3/8
3 3/4
3 1/2
3 3/4
3 3/4
3 1/2
46,400
54,400
46,200
45,100
48,700
XT546 3/4
6 5/8
4
4
52,000
49,900
XT557 3/8
7
3 5/8
4
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 8 5 81,200
XT69 8 1/2 5 1/4 100,300
TAB 2 RSHandbook_DSC.indd Sec1:16TAB 2 RSHandbook_DSC.indd Sec1:16 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
17
Note: Applies to drill pipe and heavy weight drill pipe tool joints.
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 1 3/4 5,000
XT-M31
4
4
3 7/8
2
2 1/8
2 1/8
10,800
9,700
8,500
XT-M34 4 1/4 2 9/16 9,700
XT-M384 3/4
4 3/4
2 9/16
2 11/16
16,700
14,500
XT-M39
5
5
5
4 7/8
2 7/16
2 9/16
2 13/16
2 11/16
23,300
22,300
17,700
18,900
XT-M40 5 1/4 2 11/16 26,200
XT-M435 1/4
5 1/4
3
3 1/4
23,500
19,500
XT-M46 6 1/4 3 45,100
XT-M50
6 5/8
6 1/2
6 1/4
6 1/4
3 1/2
3 3/4
3 1/2
3 5/8
50,300
42,100
40,700
38,900
XT-M54 6 3/8 4 41,500
XT-M57
7 1/4
7
7
7
4 1/4
4 1/8
4 1/4
4
51,900
56,500
51,600
58,700
XT-M65 8 5 74,600
XT-M69 8 1/2 5 1/4 92,900
TAB 2 RSHandbook_DSC.indd Sec1:17TAB 2 RSHandbook_DSC.indd Sec1:17 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
18
GPDS® Tool Joint Make-up Torque Chart
Note: Applies to drill pipe and heavy weight drill pipe tool joints.
Type Connection
Box OD(in)
Pin ID(in)
GPDS®Recommended MUT
(ft-lb)
GPDS26
3 3/8
3 1/2
3 1/2
1 3/4
1 11/16
1 5/8
5,200
5,800
6,300
GPDS314 1/8
4 1/8
2
1 7/8
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
TAB 2 RSHandbook_DSC.indd Sec1:18TAB 2 RSHandbook_DSC.indd Sec1:18 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
19
Note: Applies to drill pipe and heavy weight drill pipe tool joints.
HT® Tool Joint Make-up Torque Chart
Type Connection
Box OD(in)
Pin ID(in)
HT®Recommended MUT
(ft-lb)
2 3/8 HTSLH903 1/8
3 1/8
1.975
1 3/4
4,600
5,600
2 7/8 HTPAC3 1/8
3 1/8
1 1/2
1 3/8
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 1/2
5 1/4
5 1/4
5 1/8
5 1/8
2 9/16
2 13/16
2 11/16
2 11/16
2 9/16
24,000
19,200
21,500
20,100
21,100
HT466 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 1/2
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
39,600
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
TAB 2 RSHandbook_DSC.indd Sec1:19TAB 2 RSHandbook_DSC.indd Sec1:19 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
20
The following sections provide general guidelines for running and handling double-shouldered connections. Connection-specific procedures are available directly from NOV Grant Prideco and can be downloaded from: www.nov.com/grantprideco
Tool Joint Break-inMost 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.
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.
TAB 2 RSHandbook_DSC.indd Sec1:20TAB 2 RSHandbook_DSC.indd Sec1:20 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
21
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 connec-tions.
• 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. High-speed 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.
TAB 2 RSHandbook_DSC.indd Sec1:21TAB 2 RSHandbook_DSC.indd Sec1:21 12/20/2010 9:41:48 AM12/20/2010 9:41:48 AM
22
Application of Thread Compound to Double-Shouldered Connections• All contacting surfaces – the threads, the primary shoulders, second-
ary 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 comple-tion 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.
15° Metal Seal
SecondaryShoulder
Threads
PrimaryShoulder
TAB 2 RSHandbook_DSC.indd Sec1:22TAB 2 RSHandbook_DSC.indd Sec1:22 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
23
Tonging and Proper Gripping of the Box During Makeup• Tongs should be placed per chart below:
See Chart, column B.
Recommended Tonging Area
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
XT-M™, GT-M™, XT® long
counterbore2 6 8
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.
TAB 2 RSHandbook_DSC.indd Sec1:23TAB 2 RSHandbook_DSC.indd Sec1:23 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
24
P
P
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.
H max
TAB 2 RSHandbook_DSC.indd Sec1:24TAB 2 RSHandbook_DSC.indd Sec1:24 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
25
Box
Pin
Contact of sharp edge of pin thread on box flank
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 connec-tions should be verified before spinning up.
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.
TAB 2 RSHandbook_DSC.indd Sec1:25TAB 2 RSHandbook_DSC.indd Sec1:25 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
26
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.
TAB 2 RSHandbook_DSC.indd Sec1:26TAB 2 RSHandbook_DSC.indd Sec1:26 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
27
Milled hardness flat
Punch marks
Apply punch marks in line with hardness flat to make them easier to find.
• 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 con-nection 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
Downhole Make-up
TAB 2 RSHandbook_DSC.indd Sec1:27TAB 2 RSHandbook_DSC.indd Sec1:27 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
28
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 size- specific 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.
TAB 2 RSHandbook_DSC.indd Sec1:28TAB 2 RSHandbook_DSC.indd Sec1:28 12/20/2010 9:41:49 AM12/20/2010 9:41:49 AM
29
Box
1 2 3
Pin
NOV Grant Prideco Benchmark
Unlike the API "tangent bar", the NOV Grant Prideco benchmark step
provides a reference that is visible from any position around the
connection circumference.
1
1
1 2 3
TAB 2 RSHandbook_DSC.indd Sec1:29TAB 2 RSHandbook_DSC.indd Sec1:29 12/20/2010 9:41:50 AM12/20/2010 9:41:50 AM
30
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.
TAB 2 RSHandbook_DSC.indd Sec1:30TAB 2 RSHandbook_DSC.indd Sec1:30 12/20/2010 9:41:50 AM12/20/2010 9:41:50 AM
31
• The box depth can be checked with a dial indicator or depth microm-eter. 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.
Checking Box Depth
TAB 2 RSHandbook_DSC.indd Sec1:31TAB 2 RSHandbook_DSC.indd Sec1:31 12/20/2010 9:41:50 AM12/20/2010 9:41:50 AM
32
Box Seal
Pin Seal
0.188
0.060
0.060
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 pro-truding 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.
TAB 2 RSHandbook_DSC.indd Sec1:32TAB 2 RSHandbook_DSC.indd Sec1:32 12/20/2010 9:41:50 AM12/20/2010 9:41:50 AM
33
Beve
lDi
aNo
seDi
aPi
n Cy
linde
rDi
a
Thre
ad Fo
rm
Pin
Leng
th
Field Inspection Drawing – Pin
TAB 2 RSHandbook_DSC.indd Sec1:33TAB 2 RSHandbook_DSC.indd Sec1:33 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
34
TurboTorque® Field Inspection Dimensions – Pin
Connection Thread1Radius
Pin Length (in)
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
TurboTorque 485 TT 0.75 / 3.5 5.554-5.563 5.701-5.858 4.919-4.965 4.383-4.430
TurboTorque 500 TT 1.00 / 3.0 5.304-5.313 5.960-6.117 5.076-5.122 4.452-4.499
TurboTorque 525 TT 1.00 / 3.0 5.741-5.750 6.160-6.317 5.326-5.372 4.665-4.712
TurboTorque 550 TT 1.00 / 3.0 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
TurboTorque 690 TT 1.25 / 3.0 5.429-5.438 7.936-8.093 6.962-7.008 6.184-6.231
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.
TAB 2 RSHandbook_DSC.indd Sec1:34TAB 2 RSHandbook_DSC.indd Sec1:34 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
35
TurboTorque-M™ Field Inspection Dimensions – Pin
Connection Thread1 Radius
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
TurboTorque-M 390 TT 0.75 / 3.5 4.995 - 5.000 4.675-4.832 3.969-4.015 3.311
TurboTorque-M 420 TT 0.75 / 3.5 5.120 - 5.125 5.012-5.169 4.269-4.315 3.603
TurboTorque-M 435 TT 0.75 / 3.5 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
TurboTorque-M 500 TT 1.00 / 3.0 5.745 - 5.750 5.960-6.117 5.076-5.122 4.267
TurboTorque-M 525 TT 1.00 / 3.0 6.183 - 6.188 6.160-6.317 5.326-5.372 4.480
TurboTorque-M 550 TT 1.00 / 3.0 5.183 - 5.188 6.353-6.510 5.576-5.622 4.814
TurboTorque-M 585 TT 1.00 / 3.0 5.495 - 5.500 6.766-6.923 5.926-5.972 5.138
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.
TAB 2 RSHandbook_DSC.indd Sec1:35TAB 2 RSHandbook_DSC.indd Sec1:35 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
36
XT® Field Inspection Dimensions – Pin
Connection Thread1Radius
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. 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.
TAB 2 RSHandbook_DSC.indd Sec1:36TAB 2 RSHandbook_DSC.indd Sec1:36 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
37
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. 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.
TAB 2 RSHandbook_DSC.indd Sec1:37TAB 2 RSHandbook_DSC.indd Sec1:37 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
38
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: 1. 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.
TAB 2 RSHandbook_DSC.indd Sec1:38TAB 2 RSHandbook_DSC.indd Sec1:38 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
39
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: 1. 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.
TAB 2 RSHandbook_DSC.indd Sec1:39TAB 2 RSHandbook_DSC.indd Sec1:39 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
40
Beve
lDi
aCo
unte
rbor
eDi
a
Coun
terb
ore
Wal
l
Box D
epth
Field Inspection Drawing – Box
Thre
ad Fo
rm
TAB 2 RSHandbook_DSC.indd Sec1:40TAB 2 RSHandbook_DSC.indd Sec1:40 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
41
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: 1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco.
TAB 2 RSHandbook_DSC.indd Sec1:41TAB 2 RSHandbook_DSC.indd Sec1:41 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
42
TurboTorque-M™ Field Inspection Dimensions – Box
Connection Thread Radius1
Box Depth (in)
Bevel Dia (in)
Counterbore Dia (in)
Min C Bore Wall (in)
TurboTorque-M 380 TT 0.75/3.5 5.123-5.128 4.524-4.681 3.946-4.008 0.25
TurboTorque-M 390 TT 0.75/3.5 4.998-5.003 4.675-4.832 4.046-4.108 0.25
TurboTorque-M 420 TT 0.75/3.5 5.123-5.128 5.012-5.169 4.346-4.408 0.25
TurboTorque-M 435 TT 0.75/3.5 5.061-5.066 5.151-5.308 4.496-4.558 0.313
TurboTorque-M 485 TT 0.75/3.5 5.998-6.003 5.701-5.858 4.996-5.058 0.313
TurboTorque-M 500 TT 1.00/3.0 5.750-5.755 5.960-6.117 5.158-5.220 0.313
TurboTorque-M 525 TT 1.00/3.0 6.188-6.193 6.160-6.317 5.408-5.470 0.313
TurboTorque-M 550 TT 1.00/3.0 5.188-5.193 6.353-6.510 5.658-5.720 0.313
TurboTorque-M 585 TT 1.00/3.0 5.500-5.505 6.766-6.923 6.008-6.070 0.313
Note: 1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco.
TAB 2 RSHandbook_DSC.indd Sec1:42TAB 2 RSHandbook_DSC.indd Sec1:42 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
43
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.
TAB 2 RSHandbook_DSC.indd Sec1:43TAB 2 RSHandbook_DSC.indd Sec1:43 12/20/2010 9:41:51 AM12/20/2010 9:41:51 AM
44
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.
TAB 2 RSHandbook_DSC.indd Sec1:44TAB 2 RSHandbook_DSC.indd Sec1:44 12/20/2010 9:41:52 AM12/20/2010 9:41:52 AM
45
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: 1. 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.
TAB 2 RSHandbook_DSC.indd Sec1:45TAB 2 RSHandbook_DSC.indd Sec1:45 12/20/2010 9:41:52 AM12/20/2010 9:41:52 AM
46
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: 1. 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.
TAB 2 RSHandbook_DSC.indd Sec1:46TAB 2 RSHandbook_DSC.indd Sec1:46 12/20/2010 9:41:52 AM12/20/2010 9:41:52 AM
HEA
VY W
EIGH
TD
RILL PIPE
Heavy Weight Drill Pipe
Standard 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 HWDP – Developed to provide a gradual transition from the
heavy drill collar to the relatively lightweight drill pipe.
47
24”
DTool Joint
OD
BUpset Diameter
ANominal Size
CWear Section
Upset Diameter
BElevator Upset
Diameter
18°
18°
26”
24”
31’ Nominal Length
GP-7033 Handbook_Tabs.indd 5GP-7033 Handbook_Tabs.indd 5 11/18/2010 5:36:06 PM11/18/2010 5:36:06 PM
Heavy Weight Drill Pipe
• Tri-Spiral™ HWDP – Developed for high-angle applications such as
extended reach and horizontal drilling.
– Equally spaced, three spiral upset design helps improve cuttings
removal, reduce differential sticking tendencies and torque and
drag.
Tri-Spiral Heavy Weight Drill Pipe
48
p
DPin Tool
Joint
CSpiral Upset
C Center Spiral Upset
CSpiral Upset
DBox Tool
Joint
BElevator
Upset Diameter
BUpset Diameter
ANominal Size
31’ Nominal Length
24”
26”
26”
26”
24”
GP-7033 Handbook_Tabs.indd 6GP-7033 Handbook_Tabs.indd 6 11/18/2010 5:36:07 PM11/18/2010 5:36:07 PM
49
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
31’ Nominal Length
24”
DBox Tool
Joint
BElevator Upset
Diameter
CSpiral Upset
ANominal
Size
DPin Tool
Joint
42”
21'4”
9”
24”
TAB 3 RSHandbook_Heavyweight.indd 49TAB 3 RSHandbook_Heavyweight.indd 49 11/18/2010 5:37:31 PM11/18/2010 5:37:31 PM
50
Dimensional Data - Range IISt
anda
rd H
eavy
Wei
ght D
rill P
ipe
Tube
Tool
Join
tAs
sem
bly
Nom
inal
Dim
ensio
nsM
echa
nica
l Pr
oper
ties
Nom
inal
Dim
ensio
nsM
echa
nica
l Pr
oper
ties
Adju
sted
W
eigh
t
Nom
inal
Size (A
)
ID (in)
Wal
lTh
ickne
ss
(in)
Area
(sq in
)
Sect
ion
Mod
ulus
(cu in
)
Spira
lUp
set D
ia(C
)(in
)
End
Upse
t Dia
(B)
(in)
Tens
ileYi
eld
(lb)
Tors
iona
lYi
eld
(ft-lb
)
Conn
ectio
nSi
ze an
d Typ
e
OD (D)
(in)
ID (in)
Tens
ileYi
eld
(lb)
Tors
iona
lYi
eld
(ft-lb
)
Per
Foot
(lb)
Per
31 ft
Join
t (lb
)
Mak
e-up
Torq
ue
(ft-lb
)
3 1/
22
1/16
0.71
96.
282
3.70
24
3 7/
834
5,50
019
,600
NC
38 (3
1/2
IF)
4 3/
4 2
1/1
686
7,10
019
,200
25.6
579
511
,500
3 1/
22
1/4
0.62
55.
645
3.49
04
3 7/
831
0,50
018
,500
NC
38 (3
1/2
IF)
HT®
38
XT®
39
4 3/
44
7/8
4 7/
82
1/4
790,
900
790,
900
871,
700
19,2
0034
,200
40,7
00
23.4
823
.96
23.9
6
728
743
743
11,5
0020
,500
24,4
00
42
9/16
0.71
97.
411
5.22
54
1/2
4 3/
1640
7,60
027
,600
NC
40 (4
FH
)XT
® 39
5 1/
44
7/8
2 9/
1683
8,30
072
9,70
027
,800
37,0
0029
.92
28.4
092
888
014
,600
22,2
00
4 1/
22
3/4
0.87
59.
965
7.69
85
4 11
/16
548,
100
40,7
00N
C 46
(4 IF
)6
1/4
2 3/
41,
183,
900
44,9
0041
.45
1,28
523
,200
53
1.00
012
.566
10.6
815
1/2
5 1/
869
1,20
056
,500
NC
50 (4
1/2
IF)
HT®
50
6 5/
83
1416
,200
58,0
0088
,000
50.3
81,
562
30,0
0053
,300
5 1/
23
1/4
1.12
515
.463
14.3
426
5 11
/16
850,
400
75,9
005
1/2
FHH
T®55
7 1/
43
1/4
1,77
8,30
078
,500
115,
100
61.6
31,
911
41,2
0069
,000
*
5 7/
84
0.93
814
.542
15.6
306
3/8
679
9,80
082
,700
XT®5
77
41,
403,
100
106,
200
57.4
21,
780
63,7
00*
6 5/
84
1/2
1.06
318
.574
22.4
767
1/8
6 15
/16
1,02
1,60
011
8,90
06
5/8
FH8
4 1/
21,
896,
100
88,0
0071
.43
2,21
450
,500
Note
s: To
rque
figu
res w
ith *
indi
cate
redu
ced m
ake u
p for
typi
cally
cham
fere
d con
nect
ion.
TAB 3 RSHandbook_Heavyweight.indd 50TAB 3 RSHandbook_Heavyweight.indd 50 11/18/2010 5:37:38 PM11/18/2010 5:37:38 PM
51
Dimensional Data - Range IITR
I-SPI
RAL™
Hea
vy W
eigh
t Dril
l Pip
e
Tube
Tool
Join
tAs
sem
bly
Nom
inal
Dim
ensio
nsM
echa
nica
l Pr
oper
ties
Nom
inal
Dim
ensio
nsM
echa
nica
l Pr
oper
ties
Adju
sted
W
eigh
t
Nom
inal
Size (A)
ID (in)
Wal
lTh
ickne
ss
(in)
Area
(sq in
)
Sect
ion
Mod
ulus
(cu in
)
Spira
lUp
set D
ia(C
)(in
)
End
Upse
t Dia
(B)
(in)
Tens
ileYi
eld
(lb)
Tors
iona
lYi
eld
(ft-lb
)
Conn
ectio
nSi
ze an
dTy
pe
OD (D)
(in)
ID (in)
Tens
ileYi
eld
(lb)
Tors
iona
lYi
eld
(ft-lb
)
Per
foot
(in)
Per
31 ft
Join
t (lb
)
Mak
e-up
Torq
ue
(ft-lb
)
3 1/
22
1/16
0.71
96.
282
3.70
24
3 7/
834
5,50
019
,600
NC
38 (3
1/2
IF)
4 3/
4 2
1/1
686
7,10
019
,200
27.0
583
911
,500
3 1/
22
1/4
0.62
55.
645
3.49
04
3 7/
831
0,50
018
,500
NC
38 (3
1/2
IF)
HT®
38
XT®
39
4 3/
44
7/8
4 7/
82
1/4
790,
900
790,
900
871,
700
19,2
0034
,200
40,7
00
24.8
825
.36
25.3
6
771
786
786
11,5
0020
,500
24,4
00
42
9/16
0.71
97.
411
5.22
54
1/2
4 3/
1640
7,60
027
,600
NC
40 (4
FH
)XT
® 39
5 1/
44
7/8
2 9/
1683
8,30
072
9,70
027
,800
37,0
0031
.51
29.9
997
793
014
,600
22,2
00
4 1/
22
3/4
0.87
59.
965
7.69
85
4 11
/16
548,
100
40,7
00N
C 46
(4 IF
)6
1/4
2 3/
41,
183,
900
44,9
0043
.31
1,34
323
,200
53
1.00
012
.566
10.6
815
1/2
5 1/
869
1,20
056
,500
NC
50 (4
1/2
IF)
HT®
50
6 5/
83
1416
,200
58,0
0088
,000
52.3
41,
623
30,0
0053
,300
5 1/
23
1/4
1.12
515
.463
14.3
426
5 11
/16
850,
400
75,9
005
1/2
FHH
T® 5
57
1/4
3 1/
41,
778,
300
78,5
0011
5,10
063
.78
1,97
741
,200
69,0
00*
5 7/
84
0.93
814
.542
15.6
306
3/8
679
9,80
082
,700
XT®5
77
41,
403,
100
106,
200
57.4
21,
780
63,7
00*
6 5/
84
1/2
1.06
318
.574
22.4
767
1/8
6 15
/16
1,02
1,60
011
8,85
06
5/8
FH8
4 1/
21,
896,
100
88,0
0074
.67
2,31
550
,500
Note
s: To
rque
figu
res w
ith *
indi
cate
redu
ced m
ake u
p for
typi
cally
cham
fere
d con
nect
ion.
TAB 3 RSHandbook_Heavyweight.indd 51TAB 3 RSHandbook_Heavyweight.indd 51 11/18/2010 5:37:38 PM11/18/2010 5:37:38 PM
52
Dimensional Data - Range IISP
IRAL
-WAT
E® D
rill P
ipe m
echa
nica
l pro
pert
ies
Tube
Tool
Join
tAs
sem
bly
Nom
inal
Dim
ensio
nsM
echa
nica
l Pr
oper
ties
Nom
inal
Dim
ensio
nsM
echa
nica
l Pr
oper
ties
Adju
sted
W
eigh
t
Nom
inal
Size (A)
ID (in)
Wal
lTh
ickne
ss
(in)
Area
(sq in
)
Sect
ion
Mod
ulus
(cu in
)
Spira
lUp
set D
ia(C
)(in
)
End
Upse
t Dia
(B)
(in)
Tens
ileYi
eld
(lb)
Tors
iona
lYi
eld
(ft-lb
)
Conn
ectio
nSi
ze an
dTy
pe
OD (D)
(in)
ID (in)
Tens
ileYi
eld
(lb)
Tors
iona
lYi
eld
(ft-lb
)
Per
foot (lb
)
Per
31 ft
Join
t (l
b)
Mak
e-up
Torq
ue
(ft-lb
)
3 3/
161
20.
594
4.84
02.
687
3 5/
16N
/A53
2,40
028
,400
SLH
903
7/8
240
7,00
012
,000
19.4
860
46,
300
3 1/
22
1/4
0.62
55.
645
3.49
04
3 5/
831
0,50
018
,500
NC
38 (3
1/2
IF)
HT®
38
HT®
39
4 7/
82
1/4
790,
000
790,
900
871,
400
22,9
0034
,200
40,7
0030
.39
942
13,1
0020
,500
24,4
00
42
9/16
0.71
97.
411
5.22
54
1/2
4 1/
840
7,60
027
,600
NC
40 (4
FH
)XT
® 39
5 2
9/16
838,
300
729,
700
20,9
0040
,800
28.9
089
612
,600
24,5
002
4 1/
22
3/4
0.87
59.
965
7.69
85
4 5/
854
8,10
040
,700
NC
46 (4
IF)
6 1/
42
3/4
1,18
3,90
044
,900
49.5
31,
535
23,2
00
53
1.00
012
.566
10.6
815
1/2
5 1/
869
1,20
056
,500
NC
50 (4
1/2
IF)
HT®
50
6 5/
83
1,41
6,20
057
,800
88,8
0059
.16
1,83
430
,000
53,3
0002
5 1/
23
1/4
1.12
515
.463
14.3
426
5 5/
885
0,40
075
,900
5 1/
2 FH
HT®
55
73
1/4
1,77
8,30
053
,000
99,0
0069
.09
2,14
129
,200
46,3
002
5 7/
84
0.93
814
.542
16.6
306
3/8
679
9,80
082
,700
XT®
577
4 1,
403,
100
106,
200
65.3
82,
027
63,7
002
6 5/
84
1/2
1.06
318
.574
22.4
767
1/8
6 3/
41,
021,
600
118,
900
6 5/
8 FH
84
1/2
1,89
6,10
088
,000
82.1
22,
546
50,5
00
Note
s: 1.
3-3/
16 in
ch Sp
iral-W
ate,
pre
viou
sly re
ferr
ed to
as 2-
7/8 i
nch,
is o
nly m
anuf
actu
red a
s an
inte
gral
(non
-wel
ded)
des
ign.
2.
Red
uced
mak
eup f
or ty
pica
lly ch
amfe
red c
onne
ctio
n.
TAB 3 RSHandbook_Heavyweight.indd 52TAB 3 RSHandbook_Heavyweight.indd 52 11/18/2010 5:37:38 PM11/18/2010 5:37:38 PM
DRILL
COLLA
RS
Drill CollarsCare 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.
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 install-
ing 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
GP-7033 Handbook_Tabs.indd 7GP-7033 Handbook_Tabs.indd 7 11/18/2010 5:36:11 PM11/18/2010 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 limit-
ed industry experience and testing of available types/sizes.
Slip and Elevator Grooves
54
3”
A
B
C
3”3”
16”
18”
20”
Slip Grooved Elevator and Slip Grooved(zip grooved)
RCold Work
Shoulder Area
2” Radius
1” Radius
2” Radius
3”
18”
20”
GP-7033 Handbook_Tabs.indd 8GP-7033 Handbook_Tabs.indd 8 11/18/2010 5:36:11 PM11/18/2010 5:36:11 PM
55
Materials Mechanical Properties
Slip and Elevator Recess Dimensions
Drill Collar Diameter
Min. Yield Strength
Min. Tensile Strength
Min Hardness
(in) (psi) (psi) (BHN)
3-1/8 thru 6-7/8 110,000 140,000 285
7 thru 11 100,000 135,000 285
DrillCollar
Diameter
ElevatorRecess
Diameter
SlipRecess
Diameter
ElevatorRecessRadius
A B C R(in) (in) (in) (in)
4 1/8 3 11/16 3 3/4 1/8
4 3/4 4 1/4 4 3/8 1/8
5 4 1/2 4 5/8 1/8
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
7 3/4 7 7 1/4 3/16
8 7 1/4 7 1/2 3/16
8 1/4 7 1/2 7 3/4 3/16
8 1/2 7 3/4 8 3/16
9 8 1/8 8 1/2 1/4
9 1/2 8 5/8 9 1/4
9 3/4 8 7/8 9 1/4 1/4
10 9 1/8 9 1/2 1/4
11 10 1/8 10 1/2 1/4
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.
TAB 4 RSHandbook_Drill Collar.indd 55TAB 4 RSHandbook_Drill Collar.indd 55 11/18/2010 5:38:36 PM11/18/2010 5:38:36 PM
56
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Connection Bore of Drill Collar (in)Size Type OD (in) 1 1 1/4
API NC 23
3*2,500 *2,500*3,300 *3,300
3 1/8*3,300 *3,300*4474 *4474
3 1/44,000 3,4005423 *4610
2 7/8 PAC3
3*3,800*5152
3 1/8*5,000
6644
3 1/45,2007050
2 3/8
API
2 3/8
API IF or
NC 26 or
Slim Hole
3 1/2*4,600*6237
3 3/45,5007457
2 7/8
3 1/2
2 7/8
Extra Hole or
Dbl. Streamline
or
Mod. Open
3 3/4*4,100*5559
3 7/8*5,400*7186
4 1/8*8,100*10847
2 7/8
API
3 1/2
API IF or
NC 31 or
Slim Hole
3 7/8*4,600*6237
4 1/8*7,400*9897
4 1/4*8,800*11931
4 1/210,30013558
API NC 35
4 1/2
4 3/4
5
3 1/2
4
3 1/2
Extra Hole or
Slim Hole or
Mod. Open
4 1/4
4 1/2
4 3/4
5
5 1/4
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 56TAB 4 RSHandbook_Drill Collar.indd 56 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
57
Bore of Drill Collar (in)1 1/2 1 3/4 2 2 1/4 2 1/2 2 13/16
*2,500*3,300
2,6003525
2,6003525
*3,800 2,900 *5152 3932
4,200 2,900 5694 3932
4,200 2,900 5694 3932
*4,600 3,700 *6237 5017
4,700 3,700 6372 5017
*4,100 *4,100 *5559 *5559
*5,400 *5,400*7186 7186
*8,100 7,400 *10847 10033
*4,600 *4,600 *4,600*6237 *6237 *6237
*7,400 *7,400 6,900*9897 *9897 9220
*8,900 8,200 6,900*11931 10982 9220
9,300 8,200 6,90012609 10982 9220
*9,000 *9,000 *9,000 7,400*12067 *12067 *12067 10033
12,300 *10,800 9,200 7,40016405 14643 12474 10033
12,300 10,800 9,200 7,40016405 14643 12474 10033
*5,200 *5,200 *5,200 *5,2006915 6915 6915 6915
*8,500 *8,500 *8,500 *8,300*11389 11389 11389 11118
*12,000 11,800 10,100 8,300*16134 15863 13558 11118
13,300 11,800 10,100 8,30017897 15863 13558 11118
13,400 11,800 10,100 8,30017897 15863 13558 11118
Foot-PoundsNewton-Meters
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 57TAB 4 RSHandbook_Drill Collar.indd 57 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
58
Connection Bore of Drill Collar (in)Size Type OD (in) 1 1 1/4 1 1/2
3 1/2
API
4 1/2
API IF or
NC 38 or
Slim Hole
4 3/4
5
5 1/4
5 1/2
3 1/2 H 904
4 3/4
5
5 1/4
5 1/2
4
API
4
4 1/2
Full Hole
NC 40 or
Mod Open or
Dbl. Streamline
5
5 1/4
5 1/2
5 3/4
6
4 H 904
5 1/4
5 1/2
5 3/4
6
6 1/4
4 1/2 API Regular
5 1/2
5 3/4
6
6 1/4
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 58TAB 4 RSHandbook_Drill Collar.indd 58 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
59
Bore of Drill Collar (in)1 3/4 2 2 1/4 2 1/2 2 13/16
*10,000 *10,000 *10,000 *10,000 *8,30013423 13423 13423 13423 *11253
*13,900 *13,900 12,900 11,000 8,300*18710 *18710 17354 14778 11253
16,200 14,600 12,900 11,000 8,30021693 19795 17354 14778 11253
16,200 14,600 12,900 11,000 8,30021693 19795 17354 14778 11253
*8,800 *8,800 *8,800 *8,800 *8,800*11796 *11796 *11796 *11796 *11796
*12,800 *12,800 *12,800 12,800 10,400*17219 *17219 *17219 17219 14101
*17,100 16,900 15,100 13,200 10,400*22913 22642 20337 17761 14101
18,500 16,900 15,100 13,200 10,40025083 22642 20337 17761 14101
*10,900 *10,900 *10,900 *10,900 *10,900*14643 *14643 *14643 *14643 *14643
*15,300 *15,300 *15,300 15,000 12,100*20473 *20473 *20473 20066 16405
*20,000 18,900 17,000 15,000 12,100*26710 25218 22913 20066 16405
20,500 18,900 17,000 15,000 12,10027659 25218 22913 20066 16405
20,500 18,900 17,000 15,000 12,10027659 25218 22913 20066 16405
*12,600 *12,600 *12,600 *12,600*16948 *16948 *16948 *16948
*17,400 *17,400 *17,400 *16,500*23456 *23456 *23456 22371
*22,300 21,500 19,500 16,500*30235 *29150 26303 22371
23,700 21,700 19,400 16,50031862 29150 26303 22371
23,700 21,700 19,500 16,50031862 29150 26303 22371
*15,600 *15,600 *15,600 *15,600*20880 *20880 *20880 *20880
*20,600 *20,600 19,600 16,600*27523 *27523 26303 21964
23,700 21,700 19,600 *16,60031726 29286 26303 21964
23,700 21,700 19,600 16,60031726 29286 26303 21964
Foot-PoundsNewton-Meters
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 59TAB 4 RSHandbook_Drill Collar.indd 59 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
60
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Connection Bore of Drill Collar (in)Size Type OD in 1 1/2 1 3/4 2
API NC 44
5 3/4*20,900*27930
625,50033895
6 1/425,50033895
6 1/225,50033895
4 1/2 API Full Hole
5 1/2*13,000*17490
5 3/4*18,100*24269
6 *23,600*31591
6 1/4 27,30036607
6 1/2 27,30036607
4 1/2
API
4
4 1/2
5
4 1/2
Extra Hole
NC 46
API IF
Semi F
Dbl Streamline
Mod Open
5 3/4
6
6 1/4
6 1/2
6 3/4
4 1/2 H 904
5 3/4
6
6 1/4
6 1/2
6 3/4
5 H 904
6 1/4
6 1/2
6 3/4
7
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 60TAB 4 RSHandbook_Drill Collar.indd 60 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
61
Bore of Drill Collar (in)2 1/4 2 1/2 2 13/16 3 3 1/4
*20,900 *20,900 18,100*27930 *27930 24405
23,500 21,300 18,20031591 28743 24405
23,500 21,300 18,20031591 28743 24405
23,500 21,300 18,20031591 28743 24405
*13,000 *13,000 *13,000 *13,000*17490 *17490 *17490 *17490
*18,100 *18,100 *18,100 17,900*24269 *24269 *24269 23998
*23,600 23,000 19,900 17,900*31591 30913 26845 23998
*25,300 23,000 19,900 17,90033895 30913 26845 23998
25,300 23,000 19,900 17,90033895 30913 26845 23998
*17,700 *17,700 *17,700 *17,700*23862 *23862 *23862 *23862
*23,400 *23,400 22,400 20,30031455 31455 30099 27388
28,000 25,700 22,400 20,30037963 34573 30099 27388
28,000 25,700 22,400 20,30037963 34573 30099 27388
28,000 25,700 22,400 20,30037963 34573 30099 27388
*18,000 *18,000 *18,000 *18,000*23862 *23862 *23862 *23862
*23,700 *23,700 23,200 21,100*31726 *31726 31184 28472
28,700 26,400 23,200 21,10038641 35251 31184 28472
28,700 26,400 23,200 21,10038641 35251 31184 28472
28,700 26,400 23,200 21,10038641 35251 31184 28472
*25,400 *25,400 *25,400 *25,400*33895 *33895 *33895 *33895
*31,900 *31,900 29,400 27,200*42708 *42708 39997 36607
35,300 32,800 29,400 27,20047453 44742 39997 36607
35,300 32,800 29,400 27,20047453 44742 39997 36607
Foot-PoundsNewton-Meters
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 61TAB 4 RSHandbook_Drill Collar.indd 61 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
62
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Connection Bore of Drill Collar (in)Size Type OD (in) 2 2 1/4 2 1/2
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 1/4*23,000 *23,000*30913 *30913
6 1/2*29,700 *29,700
39997 *39997
6 3/4*36,700 35,800*48809 48132
738,400 35,80051521 48132
7 1/438,400 35,80051521 48132
7 1/238,400 35,80051521 48132
5 1/2 H 904
6 3/4*34,500 *34,500*46098 46640
7*42,000 40,100*56266 54233
7 1/442,700 40,10057622 54233
7 1/242,700 40,10057622 54233
5 1/2 API Regular
6 3/4 *31,900 *31,900*42708 *42708
7*39,400 *39,400*52877 *52877
7 1/4 42,400 39,90056944 53555
7 1/2 42,400 39,90056944 53555
5 1/2 API Full Hole
7 *32,800*44064
7 1/4*41,000*54911
7 1/2 *49,700
66435
7 3/4 51,70069825
API NC 56
7 1/4*40,500
54233
7 1/2*49,100*65757
7 3/452,10069147
852,10069147
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 62TAB 4 RSHandbook_Drill Collar.indd 62 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
63
Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4*23,000 *23,000 *23,000*30913 *30913 *30913
*29,700 *29,700 26,700*39997 *39997 35929
32,300 30,000 26,70043657 40675 35929
32,300 30,000 26,70043386 40675 35929
32,300 30,000 26,70043386 40675 35929
32,300 30,000 26,70043386 40675 35929
*34,500 34,100*46098 46098
36,500 34,10049487 46098
36,500 34,10049487 46098
36,500 34,10049487 46098
*31,900 *31,900*42708 *42708
36,200 33,90048809 45420
36,200 33,90048809 45420
36,200 33,90048809 45420
32,800 32,800 *32,80044064 44064 *44064
*41,000 *41,000 *41,000*54911 *54233 *54911
47,800 45,200 41,50063723 61012 56266
47,800 45,200 41,50063723 61012 56266
*40,500 *40,500 *40,500*54233 *54233 *54233
48,200 45,700 42,10065079 61690 56944
48,200 45,700 42,10065079 61012 56944
48,200 45,700 42,10065079 61012 56944
Foot-PoundsNewton-Meters
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 63TAB 4 RSHandbook_Drill Collar.indd 63 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
64
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Connection Bore of Drill Collar (in)Size Type OD (in) 2 2 1/4 2 1/2
6 5/8 API Regular
7 1/2*46,400*62368
7 3/4*55,600*74570
857,40077282
8 1/457,40077282
6 5/8 H 904
7 1/2*46,500*62368
7 3/4*55,700*74570
860,300*80671
8 1/460,30080671
API NC 61
8 *55,100*73214
8 1/4*65,400*86772
8 1/2 72,70097619
8 3/4 72,70097619
972,70097619
5 1/2 API IF
8 *56,600*75926
8 1/4*67,100*89484
8 1/2 74,600100331
8 3/4 74,600100331
974,600100331
9 1/4 74,000100331
6 5/8 API Full Hole
8 1/2
8 3/4
9
9 1/4
9 1/2
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 64TAB 4 RSHandbook_Drill Collar.indd 64 11/18/2010 5:38:41 PM11/18/2010 5:38:41 PM
65
Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4*46,400 *46,400 *46,400*62368 *62368 *62368
53,300 50,700 46,90071858 67791 63723
53,300 50,700 46,90071858 67791 63723
53,300 50,700 46,90071858 67791 63723
*46,500 *46,500 *46,500*62368 *62368 *62368
55,700 53,600 49,900*74570 71858 67113
*56,300 53,600 49,900*75926 71858 67113
56,300 53,600 49,90075926 71858 67113
*55,100 *55,100 *55,100*73214 *73214 *73214
*65,400 *65,400 *61,600*86772 *86772 82705
68,400 65,600 61,60092196 88128 82705
68,400 65,600 61,60092196 88128 82705
68,400 65,600 61,60092196 88128 82705
*56,600 *56,600 *56,600 *56,600*75926 *75926 *75926 *75926
*67,100 *67,100 63,400 59,000*89484 *89484 85417 79993
70,300 67,400 63,400 59,00094907 90840 85417 79993
70,300 67,400 63,400 59,00094907 90840 85417 79993
70,300 67,400 63,400 59,00094907 90840 85417 79993
70,300 67,400 63,400 59,00094907 90840 85417 79993
*67,800 *67,800 *67,800 *67,800 67,200*90840 *90840 *90840 *90840 90162
*79,500 *79,500 76,700 72,100 67,200*105754 *105754 103042 97619 90162
84,000 80,100 76,700 72,100 67,200112533 108465 103042 97619 90162
84,000 80,100 76,700 72,100 67,200112533 108465 103042 97619 90162
84,000 80,100 76,700 72,100 67,200112533 108465 103042 97619 90162
Foot-PoundsNewton-Meters
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 65TAB 4 RSHandbook_Drill Collar.indd 65 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
66
Connection Bore of Drill Collar (in)Size Type OD (in) 2 2 1/4 2 1/2
API NC 70
9
9 1/4
9 1/2
9 3/4
10
10 1/4
API NC 77
10
10 1/4
10 1/2
10 3/4
11
7 H 904
8
8 1/4
8 1/2
7 5/8 API Regular
8 1/2
8 3/4
9
9 1/4
9 1/2
7 5/8 H 904
9
9 1/4
9 1/2
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 66TAB 4 RSHandbook_Drill Collar.indd 66 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
67
Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4*75,800 *75,800 *75,800 *75,800 *75,800*101686 *101686 *101686 *101686 *101686
*88,800 *88,800 *88,800 *88,800 *88,800*119312 *119312 *119312 *119312 *119312
*102,400 *102,400 101,100 96,200 91,000*136938 *136938 135582 128803 122024
108,800 105,700 101,100 96,200 91,000145073 142361 135582 128803 122024
108,800 105,700 101,100 96,200 91,000145073 142361 135582 128803 122024
108,800 105,700 101,100 96,200 91,000145073 142361 135582 128803 122024
*108,200 *108,200 *108,200 *108,200*145073 *145073 *145073 *145073
*124,100 *124,100 *124,100 *124,100*165410 *165410 *165410 *165410
*140,500 *140,500 135,100 129,400*187103 *187103 180324 173545
145,500 140,500 135,100 129,400193882 187103 180324 173545
145,500 140,500 135,100 129,400193882 187103 180324 173545
*53,500 *53,500 *53,500 *53,500*71858 *71858 *71858 *71858
*63,700 *63,700 *63,700 61,000*85417 *85417 *85417 *82027
72,100 69,300 69,300 61,00096941 92874 88128 82027
*60,400 *60,400 *60,400 *60,400*81349 *81349 *81349 *81349
*72,200 *72,200 *72,200 *72,200*96263 *96263 *96263 *96263
*84,400 *84,200 79,500 74,500*112533 *112533 107110 100331
88,600 84,200 79,500 74,500119312 112532 107110 100331
88,600 84,200 79,500 74,500119312 112532 107110 100331
*73,000 *73,000 *73,000 *73,000*97619 *97619 *97619 *97619
*86,000 *86,000 *86,000 *86,000*115922 *115922 *115922 *115922
*99,500 *99,500 *99,500 96,300*132870 *132870 *132870 129481
Foot-PoundsNewton-Meters
Refer to pages 68-69 for notes.
TAB 4 RSHandbook_Drill Collar.indd 67TAB 4 RSHandbook_Drill Collar.indd 67 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
68
Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections
Notes: Torque figures preceded by an asterisk indicate that the weaker member for the corresponding out-side 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.
Connection Bore of Drill Collar (in)Size Type OD (in) 2 2 1/4 2 1/2
8 5/8 API Regular
10
10 1/4
10 1/2
8 5/8 H 904
10 1/4
10 1/2
7
H 904
(with low
torque face)
8 3/4
9
7 5/8
API Regular
(with low
torque face)
9 1/4
9 1/2
9 3/4
10
7 5/8
H 904
(with low
torque face)
9 3/4
10
10 1/4
10 1/2
8 5/8
API Regular
(with low
torque face)
10 3/4
11
8 5/8
H 904
(with low
torque face)
10 3/4
11
11 1/4
TAB 4 RSHandbook_Drill Collar.indd 68TAB 4 RSHandbook_Drill Collar.indd 68 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
69
Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4
*109,300 *109,300 *109,300 *109,300*146428 *146428 *146428 *146428
*125,300 *125,300 *125,300 *125,300*166766 *166766 *166766 *166766
141,100 136,100 130,800 125,000188459 181680 174901 166766
*113,500 *113,500 *113,500 *113,500*152530 *152530 *152530 *152530
*130,100 *130,100 *130,100 *130,100*174223 *174223 *174223 *174223
*68,100 *68,100 67,300 62,800*91518 *91518 90162 84061
74,200 71,400 67,300 62,800100331 96263 90162 84061
*73,100 *73,100 *73,100 *73,100*97619 *97619 *97619 *97619
*86,500 *86,500 82,500 77,300*115245 *115245 111177 104398
91,800 87,300 82,500 77,300123379 117956 111177 104398
91,800 87,300 82,000 77,300123379 117956 111177 104398
*91,700 *91,700 *91,700 *91,700*123379 *123379 *123379 *123379
*106,300 *106,300 104,200 98,800*142361 *142361 140327 132870
113,900 109,200 104,200 98,800152530 146428 140327 132870
113,900 109,200 104,200 98,800152530 146428 140327 132870
*112,900 *112,900 *112,900 *112,900*151852 *151852 *151852 *151852
*130,700 *130,700 *130,700 *130,700*174901 *174901 *174901 *174901
*93,000 *93,000 *93,000 *93,000*125413 *125413 *125413 *125413
*110,800 *110,800 *110,800 *110,800*149140 *149140 *149140 *149140
*129,200 *129,200 *129,200 *129,200 *173545 *173545 *173545 *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.
Foot-PoundsNewton-Meters
TAB 4 RSHandbook_Drill Collar.indd 69TAB 4 RSHandbook_Drill Collar.indd 69 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
70
Drill Collar Spiral Options
Drill Collar
30”
3”
24”
Drill Collar with Zip Grooves
Drill Collar with Hardband Grooves
and Zip Grooves
30”
3”
TAB 4 RSHandbook_Drill Collar.indd 70TAB 4 RSHandbook_Drill Collar.indd 70 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
71
Hardbanding
TAB 4 RSHandbook_Drill Collar.indd 71TAB 4 RSHandbook_Drill Collar.indd 71 11/18/2010 5:38:42 PM11/18/2010 5:38:42 PM
72
Drill Collar Weight per Unit of Measurelb/ft, kg/m
Drill Collar OD (in)
Drill Collar ID (in)
1 1 1/4 1 1/2 1 3/4 2
2 7/8lbs/ft 19 18 16kg/m 28 27 24
3lbs/ft 21 20 18kg/m 31 30 27
3 1/8lbs/ft 22 22 20kg/m 33 33 30
3 1/4lbs/ft 26 24 22kg/m 39 36 33
3 1/2lbs/ft 30 29 27kg/m 45 43 40
3 3/4lbs/ft 35 33 32kg/m 52 49 48
4lbs/ft 40 39 37 35 32kg/m 60 58 55 52 48
4 1/8lbs/ft 43 41 39 37 35kg/m 64 61 58 55 52
4 1/4lbs/ft 46 44 42 40 38kg/m 68 65 62 60 56
4 1/2lbs/ft 51 50 48 46 43kg/m 76 74 71 68 64
4 3/4lbs/ft 54 52 50kg/m 80 77 74
5 lbs/ft 61 59 56kg/m 91 88 83
5 1/4lbs/ft 68 65 63kg/m 101 97 94
5 1/2lbs/ft 75 73 70kg/m 112 108 104
5 3/4lbs/ft 82 80 78kg/m 122 119 116
6lbs/ft 90 88 85kg/m 134 131 126
6 1/4lbs/ft 98 96 94kg/m 146 143 140
6 1/2lbs/ft 107 105 102kg/m 159 156 152
6 3/4lbs/ft 116 114 111kg/m 172 170 165
7lbs/ft 125 123 120kg/m 186 183 179
7 1/4lbs/ft 134 132 130kg/m 199 196 193
7 1/2lbs/ft 144 142 139kg/m 214 211 207
7 3/4lbs/ft 154 152 150kg/m 229 226 223
TAB 4 RSHandbook_Drill Collar.indd 72TAB 4 RSHandbook_Drill Collar.indd 72 11/18/2010 5:38:43 PM11/18/2010 5:38:43 PM
73
Drill Collar ID (in)
2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
2943
3248
3552
4161
47 4470 65
53 5079 74
60 5789 85
67 64 60100 95 89
75 72 67 64 60112 107 100 95 89
83 79 75 72 68124 118 111 107 101
91 88 83 80 76 72135 131 123 119 113 107
99 96 91 89 85 80147 143 135 132 126 119
108 105 100 98 93 89161 156 149 146 138 132
117 114 110 107 103 98 93 84174 170 163 159 153 146 138 125
127 124 119 116 112 108 103 93189 184 177 172 166 161 153 138
137 133 129 126 122 117 113 102204 198 192 187 181 174 168 152
147 144 139 136 132 128 123 112218 214 207 202 196 190 183 166
Pound per footKilogram per meter
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.
TAB 4 RSHandbook_Drill Collar.indd 73TAB 4 RSHandbook_Drill Collar.indd 73 11/18/2010 5:38:43 PM11/18/2010 5:38:43 PM
74
Drill Collar Weight
30 ft (lb), 31 ft (kg)
Drill Collar OD (in)
Drill Collar ID (in)1 1 1/4 1 1/2 1 3/4 2
8lbs/ft 165 163 160kg/m 245 242 238
8 1/4lbs/ft 176 174 171kg/m 262 257 254
8 1/2lbs/ft 187 185 182kg/m 278 275 270
9lbs/ft 210 208 206kg/m 312 309 306
9 1/2lbs/ft 234 232 230kg/m 348 345 342
9 3/4lbs/ft 248 245 243kg/m 369 364 361
10lbs/ft 261 259 257kg/m 388 385 382
11lbs/ft 317 315 313kg/m 471 468 465
12lbs/ft 379 377 374kg/m 563 560 557
Notes: 1. Refer to API Spec 7-1 Latest Edition. Latest Edition for API standard drill collar dimensions.
Drill Collar OD (in)
Drill Collar ID (in)1 1 1/4 1 1/2 1 3/4 2
2 7/8lbs 589 558 496kg 267 253 225
3lbs 651 620 558kg 295 281 253
3 1/8lbs 682 682 620kg 309 309 281
3 1/4lbs 806 744 682kg 365 337 309
3 1/2lbs 930 899 837kg 422 407 400
3 3/4lbs 1,085 1,023 992kg 492 463 450
4lbs 1,240 1,209 1,147 1,085 992kg 562 548 520 492 450
4 1/8lbs 1,333 1,271 1,209 1,147 1,085kg 604 577 548 520 492
4 1/4lbs 1,426 1,364 1,302 1,240 1,178kg 647 619 590 562 534
TAB 4 RSHandbook_Drill Collar.indd 74TAB 4 RSHandbook_Drill Collar.indd 74 11/18/2010 5:38:43 PM11/18/2010 5:38:43 PM
75
Drill Collar ID (in)2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4157 154 150 147 143 138 133 122233 229 223 218 213 205 198 181
168 165 160 158 154 149 144 133250 245 238 235 229 221 214 198
179 176 172 169 165 160 155 150266 262 256 251 245 238 230 223
203 200 195 192 188 184 179 174302 297 290 285 279 273 266 259
227 224 220 216 212 209 206 198337 333 327 321 315 311 306 294
240 237 232 229 225 221 216 211357 352 345 340 334 328 321 314
254 251 246 243 239 235 230 225377 373 366 361 355 349 342 334
310 307 302 299 295 291 286 281461 456 449 444 438 432 425 418
371 368 364 361 357 352 347 342551 547 541 537 531 523 516 508
Notes (cont): 2. For special configurations of drill collars, consult manufacturer for reduction in weight.
Drill Collar ID (in)2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
899407
992450
1,085492
Pound per footKilogram per meter
PoundKilogram
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.
TAB 4 RSHandbook_Drill Collar.indd 75TAB 4 RSHandbook_Drill Collar.indd 75 11/18/2010 5:38:43 PM11/18/2010 5:38:43 PM
76
Drill Collar Weight31 ft (lb), 31 ft (kg)
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.
Drill Collar OD(in)
Drill Collar ID (in)1 1 1/4 1 1/2 1 3/4 2
4 1/2lbs 1,581 1,550 1,488 1,426 1,333kg 717 703 675 646 604
4 3/4lbs 1,674 1,612 1,550kg 759 731 703
5lbs 1,891 1,829 1,736kg 857 829 787
5 1/4lbs 2,108 2,015 1,953kg 956 913 885
5 1/2lbs 2,325 2,263 2,170kg 1055 1026 984
5 3/4lbs 2,542 2,480 2,418kg 1152 1125 1097
6lbs 2,790 2,728 2,635kg 1266 1237 1195
6 1/4lbs 3,038 2,976 2,914kg 1378 1350 1322
6 1/2lbs 3,317 3,255 3,162kg 1505 1476 1434
6 3/4lbs 3,596 3,534 3,441kg 1631 1603 1561
7lbs 3,875 3,813 3,720kg 1758 1730 1687
7 1/4lbs 4,154 4,092 4,030kg 1884 1856 1828
7 1/2lbs 4,464 4,402 4,309kg 2025 1997 1955
7 3/4lbs 4,774 4,712 4,650kg 2165 2137 2109
8lbs 5,115 5,053 4,960kg 2320 2292 2250
8 1/4lbs 5,456 5,394 5,301kg 2475 2447 2404
8 1/2lbs 5,797 5,735 5,642kg 2629 2601 2559
9lbs 6,510 6,448 6,386kg 2953 2925 2897
9 1/2lbs 7,254 7,192 7,130kg 3290 3262 3234
9 3/4lbs 7,688 7,595 7,533kg 3487 3445 3417
10lbs 8,091 8,029 7,967kg 3670 3642 3614
11lbs 9,827 9,765 9,703kg 4457 4429 4401
12lbs 11,749 11,687 11,594kg 5329 5301 5259
TAB 4 RSHandbook_Drill Collar.indd 76TAB 4 RSHandbook_Drill Collar.indd 76 11/18/2010 5:38:44 PM11/18/2010 5:38:44 PM
77
2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 41,271
576
1,457 1,364660 618
1,643 1,550745 703
1,860 1,767843 801
2,077 1,984 1,860942 899 843
2,325 2,232 2,077 1,984 1,8601055 1012 942 899 843
2,573 2,449 2,325 2,232 2,1081167 1111 1055 1012 956
2,821 2,728 2,573 2,480 2,356 2,2321280 1237 1167 1125 1069 1012
3,069 2,976 2,821 2,759 2,635 2,4801392 1350 1280 1251 1195 1125
3,348 3,255 3,100 3,038 2,883 2,7591519 1476 1406 1378 1308 1252
3,627 3,534 3,410 3,317 3,193 3,038 2,883 2,6041645 1603 1547 1505 1448 1378 1308 1181
3,937 3,844 3,689 3,596 3,472 3,348 3,193 2,8831786 1744 1673 1631 1575 1519 1448 1308
4,247 4,123 3,999 3,906 3,782 3,627 3,503 3,1621926 1870 1814 1772 1715 1645 1589 1434
4,557 4,464 4,309 4,216 4,092 3,968 3,813 3,4722067 2024 1955 1912 1856 1800 1730 1575
4,867 4,774 4,650 4,557 4,433 4,278 4,123 3,7822208 2165 2109 2067 2011 1940 1870 1715
5,208 5,115 4,960 4,898 4,774 4,619 4,464 4,1232362 2320 2250 2222 2165 2095 2025 1870
5,549 5,456 5,332 5,239 5,115 4,960 4,805 4,6502517 2475 2419 2376 2320 2250 2180 2109
6,293 6,200 6,045 5,952 5,828 5,704 5,549 5,3942854 2812 2742 2700 2644 2587 2517 2447
7,037 6,944 6,820 6,696 6,572 6,479 6,386 6,1383192 3150 3093 3037 2981 2939 2897 2784
7,440 7,347 7,192 7,099 6,975 6,851 6,696 6,5413375 3333 3262 3220 3164 3108 3037 2967
7,874 7,781 7,626 7,533 7,409 7,285 7,130 6,9753572 3529 3459 3417 3361 3304 3234 3164
9,610 9,517 9,362 9,269 9,145 9,021 8,866 8,7114359 4317 4247 4204 4148 4092 4022 3951
11,501 11,408 11,284 11,191 11,067 10,912 10,757 10,6025217 5175 5118 5076 5020 4950 4879 4809
PoundKilogram
TAB 4 RSHandbook_Drill Collar.indd 77TAB 4 RSHandbook_Drill Collar.indd 77 11/18/2010 5:38:44 PM11/18/2010 5:38:44 PM
78
Drill Collar Bending Strength Ratios
1 1/2" ID
TAB 4 RSHandbook_Drill Collar.indd 78TAB 4 RSHandbook_Drill Collar.indd 78 11/18/2010 5:38:44 PM11/18/2010 5:38:44 PM
79
To obtain bending strength
ratio, measure OD & ID of drill
collar ar points shown in the
illustration.
1 3/4" ID
TAB 4 RSHandbook_Drill Collar.indd 79TAB 4 RSHandbook_Drill Collar.indd 79 11/18/2010 5:38:44 PM11/18/2010 5:38:44 PM
80
Drill Collar Bending Strength Ratios
2" ID
TAB 4 RSHandbook_Drill Collar.indd 80TAB 4 RSHandbook_Drill Collar.indd 80 11/18/2010 5:38:45 PM11/18/2010 5:38:45 PM
81
To obtain bending strength
ratio, measure OD & ID of drill
collar at points shown in the
illustration.
2 1/4" ID
TAB 4 RSHandbook_Drill Collar.indd 81TAB 4 RSHandbook_Drill Collar.indd 81 11/18/2010 5:38:45 PM11/18/2010 5:38:45 PM
82
Drill Collar Bending Strength Ratios
2 1/2" ID
TAB 4 RSHandbook_Drill Collar.indd 82TAB 4 RSHandbook_Drill Collar.indd 82 11/18/2010 5:38:45 PM11/18/2010 5:38:45 PM
83
To obtain bending strength
ratio, measure OD & ID of drill
collar at points shown in the
illustration.
2 1/2" ID
TAB 4 RSHandbook_Drill Collar.indd 83TAB 4 RSHandbook_Drill Collar.indd 83 11/18/2010 5:38:46 PM11/18/2010 5:38:46 PM
84
Drill Collar Bending Strength Ratios
2 13/16" ID
TAB 4 RSHandbook_Drill Collar.indd 84TAB 4 RSHandbook_Drill Collar.indd 84 11/18/2010 5:38:46 PM11/18/2010 5:38:46 PM
85
To obtain bending strength
ratio, measure OD & ID of drill
collar at points shown in the
illustration.
2 13/16" ID
TAB 4 RSHandbook_Drill Collar.indd 85TAB 4 RSHandbook_Drill Collar.indd 85 11/18/2010 5:38:46 PM11/18/2010 5:38:46 PM
86
Drill Collar Bending Strength Ratios
3" ID
TAB 4 RSHandbook_Drill Collar.indd 86TAB 4 RSHandbook_Drill Collar.indd 86 11/18/2010 5:38:47 PM11/18/2010 5:38:47 PM
87
To obtain bending strength
ratio, measure OD & ID of drill
collar at points shown in the
illustration.
3" ID
TAB 4 RSHandbook_Drill Collar.indd 87TAB 4 RSHandbook_Drill Collar.indd 87 11/18/2010 5:38:47 PM11/18/2010 5:38:47 PM
88
Drill Collar Bending Strength Ratios
3 1/4" ID
TAB 4 RSHandbook_Drill Collar.indd 88TAB 4 RSHandbook_Drill Collar.indd 88 11/18/2010 5:38:47 PM11/18/2010 5:38:47 PM
89
To obtain bending strength
ratio, measure OD & ID of drill
collar at points shown in the
illustration.
3 1/4" ID
TAB 4 RSHandbook_Drill Collar.indd 89TAB 4 RSHandbook_Drill Collar.indd 89 11/18/2010 5:38:48 PM11/18/2010 5:38:48 PM
90
Drill Collar Bending Strength Ratios
3 1/2" ID
TAB 4 RSHandbook_Drill Collar.indd 90TAB 4 RSHandbook_Drill Collar.indd 90 11/18/2010 5:38:48 PM11/18/2010 5:38:48 PM
91
To obtain bending strength
ratio, measure OD & ID of drill
collar at points shown in the
illustration.
3 1/2" ID
TAB 4 RSHandbook_Drill Collar.indd 91TAB 4 RSHandbook_Drill Collar.indd 91 11/18/2010 5:38:48 PM11/18/2010 5:38:48 PM
92
API Interchangeable Connection Table
Connection Name Size
Numbered Connection (NC) 26 31 38 40 46 50
Internal Flush (IF) 2 3/8 2 7/8 3 1/2 4 4 1/2
Slim Hole (SH) 2 7/8 3 1/2 4 4 1/2
Full Hole (FH) 4
Double Streamline (DSL) 3 1/2 4 1/2 5 1/2
Extra Hole (XH) 2 7/8 3 1/2 4 1/2 5
External Flush (EF) 4 1/2
TAB 4 RSHandbook_Drill Collar.indd 92TAB 4 RSHandbook_Drill Collar.indd 92 11/18/2010 5:38:49 PM11/18/2010 5:38:49 PM
93
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.
Ideal Drill Collar Range
Hole Size (in)
Casing Size To Be Run
(in)
Ideal Collar Drill Range API Drill Collar
Min.(in)
Max. (in)
Sizes Which Fall in the Ideal Range (in)
6 1/8 4 1/2 3.875 4.750 4 1/8, 4 3/4
6 1/4 4 1/2 3.750 4.875 4 1/8, 4 3/4
6 3/4 4 1/2 3.250 5.125 3 1/2, 4 1/8, 4 3/4, 5
7 7/84 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
8 3/85 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
8 1/26 5/8 6.280 6.750 6 1/2, 6 3/4
7 6.8121 6.750 6 3/4
8 3/46 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
9 1/27 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
9 7/87 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
10 5/87 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
11 8 5/8 8.250 8.875 8 1/4
12 1/49 5/8 9.000 10.125 9, 9 1/2, 9 3/4, 10
10 3/4 11.2502 10.125 10
13 3/4 10 3/4 9.750 11.250 9 3/4, 10, 11
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
TAB 4 RSHandbook_Drill Collar.indd 93TAB 4 RSHandbook_Drill Collar.indd 93 11/18/2010 5:38:49 PM11/18/2010 5:38:49 PM
94
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 - 12 100,0004 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 65,0003 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 80,0003 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 55,0003 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 - 12 100,0004 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 65,0003 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
Rig Tongs
TAB 4 RSHandbook_Drill Collar.indd 94TAB 4 RSHandbook_Drill Collar.indd 94 11/18/2010 5:38:49 PM11/18/2010 5:38:49 PM
SU
BS
AN
DK
EL
LY
S
Subs and Kellys
95
Types of Subs
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96
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
General Notes on Subs
Crossover Sub
GP-7033 Handbook_Tabs.indd 10GP-7033 Handbook_Tabs.indd 10 11/18/2010 5:36:11 PM11/18/2010 5:36:11 PM
97
Kelly Saver Subs
TAB 5 RSHandbook_SubsKellys.indd 97TAB 5 RSHandbook_SubsKellys.indd 97 11/18/2010 5:38:14 PM11/18/2010 5:38:14 PM
98
Bit Sub
Lift Sub
TAB 5 RSHandbook_SubsKellys.indd 98TAB 5 RSHandbook_SubsKellys.indd 98 11/18/2010 5:38:17 PM11/18/2010 5:38:17 PM
99
Bit Box Float Bores
Box Up Float Bores
TAB 5 RSHandbook_SubsKellys.indd 99TAB 5 RSHandbook_SubsKellys.indd 99 11/18/2010 5:38:17 PM11/18/2010 5:38:17 PM
100
Kelly Weights – Pounds Per FootDrive Section Only
Hexagon Kelly
Square Kelly
1 1/4 1 1/2 1 3/4 2 2 1/4 2 1/2 2 3/4 2 13/16 3 3 1/4
3 26.4 24.6 22.4
3 1/2 35.6 33.5 31.0 28.1
4 1/4 47.9 44.7 41.2 40.3
1 1/4 1 1/2 1 3/4 2 2 1/4 2 1/2 2 3/4 2 13/16 3 3 1/4
3 22.3 20.5
3 1/2 30.1 27.9 25.4 22.5
4 1/4 39.7 36.5 33.0 32.1
5 1/4 61.0 60.0 57.1 52.9
TAB 5 RSHandbook_SubsKellys.indd 100TAB 5 RSHandbook_SubsKellys.indd 100 11/18/2010 5:38:18 PM11/18/2010 5:38:18 PM
101
Nom
inal
Si
ze
Avai
labl
e Le
ngth
s (ft
)(A
)
Top U
pset
Join
tBo
ttto
m U
pset
Bore (E)
Driv
e Sec
tion
Appr
ox.
wt.
per
40 ft
(lbs
.)AP
I Box
Thre
adLe
ft Ha
nd
OD (C)
Righ
t Ha
ndCo
nnec
tions
OD (D)
Acro
ssCo
rner
s (F
)
Acro
ss
Flat
s(G
)
340
, 60
6 5/
8 Re
g.7
3/4
NC3
1(2
7/8I
F)4
1/8
1 3/
43.
875
310
904
1/2
Reg.
5 3/
4
3 1/
240
, 60
6 5/
8 Re
g.7
3/4
NC3
8(3
1/2I
F)4
3/4
2 1/
44.
437
3 1/
213
004
1/2
Reg.
5 3/
4
4 1/
440
, 60
6 5/
8 Re
g.7
3/4
NC4
6(4
IF)1
6 1/
42
13/1
65.
500
4.25
1830
4 1/
2 Re
g.5
3/4
NC5
0(4
1/2I
F)1
6 3/
8
Note
s:1.
The
low
er en
d of 4
1/4 a
nd 5
1/4 s
quar
e kel
lys h
ave t
wo s
tand
ard s
izes a
nd st
yles
of c
onne
ctio
ns.
2. A
ll di
men
sion
in in
ches
unl
ess o
ther
wise
spec
ified
.3.
Sho
rt b
oreb
ack s
tand
ard i
n to
p box
.
Square Kelly
TAB 5 RSHandbook_SubsKellys.indd 101TAB 5 RSHandbook_SubsKellys.indd 101 11/18/2010 5:38:18 PM11/18/2010 5:38:18 PM
102
Hexagonal KellyNo
min
al
Size
Avai
labl
e Le
ngth
s (ft
)(A
)
Top U
pset
Join
tBo
ttto
m U
pset
Bore (E)
Driv
e Sec
tion
Appr
ox.
wt.
per
40 ft
(lbs
.)AP
I Box
Thre
adLe
ft Ha
nd
OD (C)
Righ
t Ha
ndCo
nnec
tions
OD (D)
Acro
ssCo
rner
s (F
)
Acro
ss
Flat
s(G
)
340
, 60
6 5/
8 Re
g.7
3/4
NC2
6 (2
3/8
IF)
3 3/
81
1/2
3.37
53
1000
4 1/
2 Re
g.5
3/4
3 1/
240
, 60
6 5/
8 Re
g.7
3/4
NC3
1(2
7/8I
F)4
1/8
1 3/
43.
937
3 1/
212
904
1/2
Reg.
5 3/
4
4 1/
440
, 60
6 5/
8 Re
g.7
3/4
NC3
8(3
1/2I
F)4
3/4
2 1/
4 4.
781
4.25
1730
4 1/
2 Re
g.5
3/4
5 1/
440
, 60
6 5/
8 Re
g.7
3/4
NC4
6(4
IF)*
6 1/
42
13/1
6
5.90
05
1/4
2560
3
NC5
0(4
1/2I
F)*
6 3/
83
1/4
Note
s:1.
The
low
er en
d of 4
1/4 a
nd 5
1/4 s
quar
e kel
lys h
ave t
wo s
tand
ard s
izes a
nd st
yles
of c
onne
ctio
ns.
2. A
ll di
men
sion
in in
ches
unl
ess o
ther
wise
spec
ified
.3.
Sho
rt b
oreb
ack s
tand
ard i
n to
p box
.
TAB 5 RSHandbook_SubsKellys.indd 102TAB 5 RSHandbook_SubsKellys.indd 102 11/18/2010 5:38:18 PM11/18/2010 5:38:18 PM
103
Under ideal conditions, a new Drive Bushing assembly should be used
when picking up a new kelly. If this is not possible, the following check-
list 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.
Picking Up a New Kelly
TAB 5 RSHandbook_SubsKellys.indd 103TAB 5 RSHandbook_SubsKellys.indd 103 11/18/2010 5:38:18 PM11/18/2010 5:38:18 PM
104
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
____________________________________________
Notes
TAB 5 RSHandbook_SubsKellys.indd 104TAB 5 RSHandbook_SubsKellys.indd 104 11/18/2010 5:38:18 PM11/18/2010 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 (KWM-
OWM) ÷ (35.4-KWM)
Volume Increase in Bbls from adding Barite = Sacks Added ÷ 14.9
Volume Increase in Bbls from adding Barite = (Gel) = Sacks Added ÷ 8.75
Triplex Pump Output (bbls/stk @ 100%) = 0.000243 x Stroke Length x
(Liner Dia)2
Duplex Pump Outlet (bbl/stk @ 100%) = 0.000162 x Stroke x
[(2 x Liner Dia2) - Rod Dia2]
Annular Capacity (bbls/ft) = (ID2hole - OD2pipe) ÷ 1029
105
WELL CO
NTRO
L
GP-7033 Handbook_Tabs.indd 11GP-7033 Handbook_Tabs.indd 11 11/18/2010 5:36:12 PM11/18/2010 5:36:12 PM
Well Control
MW Mud Weight
SICP Shut in casing pressure
SIDPP Shut in drill pipe pressure
ppg Pounds per gallon
KWM Kill Weight Mud
OWM Original Weight Mud
DP Drill Pipe
Bbls Barrels
Stk Stroke
106
Capacity of DUPLEX Mud Pumps at 100% Efficiency
Liner Dia Stroke Length (in)
(in) 12 14 16 18
4 1/2 0.074 0.082 – –
5 0.089 0.104 0.113 0.128
5 1/2 0.110 0.128 0.141 0.158
6 – 0.154 0.170 0.192
6 1/2 – 0.183 0.203 0.228
7 – 0.213 0.238 0.267
7 1/2 – 0.241 0.275 0.310
(in Bbls/stroke)
Capacity of TRIPLEX Mud Pumps at 100% Efficiency
Liner Dia Stroke Length (in)
(in) 9 10 11 12
5 0.055 0.061 0.067 0.073
5 1/2 0.066 0.074 0.081 0.088
6 0.079 0.087 0.096 0.105
6 1/2 0.092 0.103 0.113 0.123
7 0.107 0.119 0.131 0.143
7 1/2 0.123 0.137 0.150 0.164
(in Bbls/stroke)
GP-7033 Handbook_Tabs.indd 12GP-7033 Handbook_Tabs.indd 12 11/18/2010 5:36:12 PM11/18/2010 5:36:12 PM
107
SizeOD
SizeID
NominalWeight Capacity Displacement
(in) (in) (lb/ft) (bbl/ft) (bbl/ft)
2 3/8 1.81 6.6 0.0032 0.0028
2 7/8 2.15 10.4 0.0045 0.0041
3 1/2 2.76 13.3 0.0074 0.0051
3 1/2 2.60 15.5 0.0066 0.0058
4 3.34 14.0 0.0108 0.0057
4 1/2 3.82 16.6 0.0142 0.0064
4 1/2 3.64 20.0 0.0129 0.0077
5 4.28 19.5 0.0178 0.0075
5 1/2 4.78 21.9 0.0222 0.0087
5 1/2 4.67 24.7 0.0211 0.0096
6 5/8 4.86 22.2 0.0229 0.0087
6 5/8 5.96 25.2 0.0346 0.0098
API Standard Drill Pipe Capacity and Displacement
Heavy Weight Drill Pipe
SizeOD
SizeID Weight Capacity Displacement
(in) (in) (lb/ft) (bbl/ft) (bbl/ft)
3 1/2 2.0625 25.3 0.00421 0.00921
4 2.5625 29.7 0.00645 0.01082
4 1/2 2.75 41.0 0.00743 0.01493
5 3.0 49.3 0.00883 0.01796
5 1/2 3.25 61.5 0.01030 0.02240
6 5/8 4.5 72.0 0.01970 0.02620
Additional capacities, displacements and weight can be determined from the following formulas:
CAPACITY = = bbls/ft
DISPLACEMENT = = bbls/ft
WEIGHT = DISPLACEMENT bbls/ft x 2747 lbs/bbl = lbs/ft
ID2
1029.4
OD2 - ID2
1029.4
TAB 6 RSHandbook_WellControl.indd 107TAB 6 RSHandbook_WellControl.indd 107 11/18/2010 5:37:53 PM11/18/2010 5:37:53 PM
108
Drill
Colla
r Cap
acity
and D
ispla
cem
ent (
bbls/
ft)OD
ID1 1
/21 3
/42
2 1/4
2 1/2
2 3/4
33 1
/43 1
/23 3
/44
4 1/4
(in)
Cap
0.00
220.
0030
0.00
390.
0049
0.00
610.
0073
0.00
870.
0103
0.01
190.
0137
0.01
550.
0175
4lb
/ft
36.7
34.5
32.0
29.2
--
--
--
--
Dis
p.0.
0133
0.01
250.
0116
0.10
6-
--
--
--
-
4 1/
4lb
/ft
42.4
40.0
37.5
34.7
--
--
--
--
Dis
p.0.
0153
0.01
450.
0136
0.01
26-
--
--
--
-
4 1/
2lb
/ft
48.1
45.9
43.4
40.6
--
--
--
--
Dis
p.0.
175
0.01
670.
0158
0.01
48-
--
--
--
-
4 3/
4lb
/ft
54.3
52.1
49.6
46.8
43.6
--
--
--
-
Dis
p.0.
0197
0.01
890.
0181
0.01
700.
0159
--
--
--
-
5lb
/ft
60.8
58.6
56.1
53.3
50.1
--
--
--
-
Dis
p.0.
0221
0.02
130.
0204
0.01
940.
0182
--
--
--
-
5 1/
4lb
/ft
67.6
65.4
62.9
60.1
56.9
53.4
--
--
--
Dis
p.0.
0246
0.02
380.
0229
0.02
190.
0207
0.01
94-
--
--
-
5 1/
2lb
/ft
74.8
72.6
70.1
67.3
64.1
60.6
56.8
--
--
-
Dis
p.0.
0272
0.02
640.
0255
0.02
450.
0233
0.02
210.
0207
--
--
-
5 3/
4lb
/ft
82.3
80.1
77.6
74.8
71.6
68.1
64.3
--
--
-
Dis
p.0.
0299
0.02
910.
0282
0.02
720.
0261
0.02
480.
0234
--
--
-
6lb
/ft
90.1
87.9
85.4
82.6
79.4
75.9
72.1
67.9
63.4
--
-
Dis
p.0.
0328
0.03
200.
0311
0.03
010.
0289
0.02
760.
0262
0.02
470.
0231
--
-
6 1/
4lb
/ft
98.0
95.8
93.3
90.5
87.3
83.8
80.0
75.8
71.3
--
-
Dis
p.0.
0356
0.03
490.
0339
0.03
290.
0318
0.03
050.
0291
0.02
760.
0259
--
-
6 1/
2lb
/ft
107.
010
4.8
102.
399
.596
.392
.889
.084
.880
.3-
--
Dis
p.0.
0389
0.03
810.
0372
0.03
620.
0350
0.03
380.
0324
0.03
080.
0292
--
-
TAB 6 RSHandbook_WellControl.indd 108TAB 6 RSHandbook_WellControl.indd 108 11/18/2010 5:37:57 PM11/18/2010 5:37:57 PM
109
Drill
Colla
r Cap
acity
and D
ispla
cem
ent (
bbls/
ft) (C
ont.)
ODID
1 1/2
1 3/4
22 1
/42 1
/22 3
/43
3 1/4
3 1/2
3 3/4
4 4 1
/4(in
)Ca
p0.
0022
0.00
300.
0039
0.00
490.
0061
0.00
730.
0087
0.01
030.
0119
0.01
370.
0155
0.01
75
6 3/
4lb
/ft
116.
011
3.8
111.
310
8.5
105.
310
1.8
98.0
93.8
89.3
--
-
Dis
p.0.
0422
0.04
140.
0405
0.03
950.
0383
0.03
700.
0356
0.03
410.
0325
--
-
7lb
/ft
125.
012
2.8
120.
311
7.5
114.
311
0.8
107.
010
2.8
98.3
93.4
88.3
-
Dis
p.0.
0455
0.04
470.
0438
0.04
270.
0416
0.04
030.
0389
0.03
740.
0358
0.03
400.
0321
-
7 1/
4lb
/ft
134.
013
1.8
129.
312
6.5
123.
311
9.8
116.
011
1.8
107.
310
2.4
97.3
-
Dis
p.0.
0487
0.04
790.
0470
0.04
600.
0449
0.04
360.
0422
0.04
070.
0390
0.03
720.
0354
-
7 1/
2lb
/ft
144.
014
1.8
139.
313
6.5
133.
312
9.8
126.
012
1.8
117.
311
2.4
107.
3-
Dis
p.0.
0524
0.05
160.
0507
0.04
970.
0485
0.04
720.
0458
0.04
430.
0427
0.04
090.
0390
-
7 3/
4lb
/ft
154.
015
1.8
149.
314
6.5
143.
313
9.8
136.
013
1.8
127.
312
2.4
117.
3-
Dis
p.0.
0560
0.05
520.
0543
0.05
330.
0521
0.05
090.
0495
0.04
790.
0463
0.04
450.
0427
-
8lb
/ft
165.
016
2.8
160.
315
7.5
154.
315
0.8
147.
014
2.8
138.
313
3.4
123.
312
2.8
Dis
p.0.
0600
0.05
920.
0583
0.05
730.
0561
0.05
490.
0535
0.05
200.
0503
0.04
850.
0467
0.04
47
8 1/
4lb
/ft
176.
017
3.8
171.
316
8.5
165.
316
1.8
158.
015
3.8
149.
314
4.4
139.
313
3.8
Dis
p.0.
0640
0.06
320.
0623
0.06
130.
0601
0.05
890.
0575
0.05
600.
0543
0.05
250.
0507
0.04
87
8 1/
2lb
/ft
187.
018
4.8
182.
317
9.5
176.
317
2.8
169.
016
4.8
160.
315
5.4
150.
314
4.8
Dis
p.0.
0680
0.06
720.
0663
0.06
530.
0641
0.06
290.
0615
0.06
000.
0583
0.05
650.
0547
0.05
27
8 3/
4lb
/ft
199.
019
6.8
194.
319
1.5
188.
318
4.8
181.
017
6.8
172.
316
7.4
162.
315
6.8
Dis
p.0.
0724
0.07
160.
0707
0.06
970.
0685
0.06
720.
0658
0.06
430.
0697
0.06
090.
0590
0.05
70
9lb
/ft
210.
220
8.0
205.
620
2.7
199.
619
6.0
192.
218
8.0
183.
517
8.7
173.
516
8.0
Dis
p.0.
0765
0.07
570.
0748
0.07
380.
0726
0.07
140.
0700
0.06
850.
0668
0.06
510.
0632
0.06
12
10lb
/ft
260.
925
8.8
256.
325
3.4
250.
324
6.8
242.
923
8.8
234.
322
9.4
224.
221
8.7
Dis
p.0.
0950
0.09
420.
0933
0.09
230.
0911
0.08
980.
0884
0.08
690.
0853
0.08
350.
0816
0.07
96
TAB 6 RSHandbook_WellControl.indd 109TAB 6 RSHandbook_WellControl.indd 109 11/18/2010 5:37:57 PM11/18/2010 5:37:57 PM
110
Buoyancy Factors
Mud Density BuoyancyFactor (Kb)(lb/gal) (lb/cu ft) (g/cc)
8.4 62.84 1.01 0.872
8.6 64.33 1.03 0.869
8.8 65.83 1.05 0.866
9.0 67.32 1.08 0.862
9.2 68.82 1.10 0.859
9.4 70.32 1.12 0.856
9.6 71.81 1.15 0.853
9.8 73.31 1.17 0.850
10.0 74.80 1.20 0.847
10.2 76.30 1.22 0.844
10.4 77.80 1.24 0.841
10.6 79.29 1.27 0.838
10.8 80.79 1.29 0.835
11.0 82.29 1.32 0.832
11.2 83.78 1.34 0.829
11.4 85.28 1.36 0.826
11.6 86.77 1.39 0.823
11.8 88.27 1.41 0.820
12.0 89.77 1.44 0.817
12.2 91.26 1.46 0.814
12.4 92.76 1.48 0.811
12.6 94.25 1.51 0.807
12.8 95.75 1.53 0.804
13.0 97.25 1.56 0.801
13.2 98.74 1.58 0.798
13.4 100.24 1.60 0.795
13.6 101.74 1.63 0.792
13.8 103.23 1.65 0.789
TAB 6 RSHandbook_WellControl.indd 110TAB 6 RSHandbook_WellControl.indd 110 11/18/2010 5:37:57 PM11/18/2010 5:37:57 PM
111
Mud Density BuoyancyFactor (Kb)(lb/gal) (lb/cu ft) (g/cc)
14.0 104.73 1.68 0.786
14.2 106.22 1.70 0.783
14.4 107.72 1.72 0.780
14.6 109.22 1.75 0.777
14.8 110.71 1.77 0.774
15.0 112.21 1.80 0.771
15.2 113.70 1.82 0.768
15.4 115.20 1.84 0.765
15.6 116.70 1.87 0.762
15.8 118.19 1.89 0.759
16.0 119.69 1.91 0.756
16.2 121.18 1.94 0.752
16.4 122.68 1.96 0.749
16.6 124.18 1.99 0.746
16.8 125.67 2.01 0.743
17.0 127.17 2.03 0.740
17.2 128.66 2.06 0.737
17.4 130.16 2.08 0.734
17.6 131.66 2.11 0.731
17.8 133.15 2.13 0.728
18.0 134.65 2.15 0.725
18.5 138.39 2.21 0.717
19.0 142.13 2.27 0.710
19.5 145.87 2.33 0.702
20.0 149.61 2.39 0.694
TAB 6 RSHandbook_WellControl.indd 111TAB 6 RSHandbook_WellControl.indd 111 11/18/2010 5:37:58 PM11/18/2010 5:37:58 PM
112
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 useppg
x (0.052) x (TVD, ft.) = psi
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• 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)
• Maximum Allowable Mud Weight, ppg (MAMW)
• 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
Converting Pressures, psi into mud weight, ppg
Anytime a pressure is to be converted to mud weight use the following formulas
Annular Pressure Loss, psi
÷ (0.052) ÷ (TVD, ft) + (OMW) = ECD, ppg
Leak-Off Pressure Loss, psi
÷ (0.052) ÷ (TVD, ft) +Test Mud
Weight = MAMW, ppg
D392002466-MKT-001 Rev 02 Handbook Cover.indd 3D392002466-MKT-001 Rev 02 Handbook Cover.indd 3 1/11/2011 10:52:36 AM1/11/2011 10:52:36 AM
© 2011 National Oilwell Varco© 2011 National Oilwell VarcoD392002466-MKT-001 Rev. 02D392002466-MKT-001 Rev. 02
O n e C o m p a n y . . . U n l i m i t e d S o l u t i o n s
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