extreme rotary shoulder handbook (dp,hw,dc)
TRANSCRIPT
DRILLING PRODUCTS & SERVICESwww.grantprideco.com
eXtreme®
RotaryShoulderHandbook
eXtreme®
RotaryShoulderHandbook
CONTENTS
SECTION IDrill Pipe
SECTION IIDouble Shoulder Connections
SECTION IIIHeavy Weight Drill Pipe
SECTION IVDrill Collars
SECTION VKellys
SECTION VISubs
SECTION VIIWell Control
This handbook is a summary of the technical data from APISpec. 7, API RP 7G, etc., for the purpose of easierapplication in the field.
Grant Prideco has produced this handbook forgeneral information only. It is not intended for designand engineering purposes. Although every effort hasbeen made to maintain the accuracy and reliability ofits contents, Grant Prideco in no way assumesresponsibility or liability for any loss, damage or injuryresulting from the use of information and data herein.All applications for the material described are at theuser's own risk and are the user's responsibility.
1
DR
ILL
PIP
EProper break-in is probably the most important factoraffecting the life of the tool joint connection. Here aresome recommendations to follow:
1. Proper make-up torque is determined by theconnection type, size, OD and ID and may befound in torque tables.
2. Make up connections slowly, preferably usingchain tongs. (High speed kelly spinners or thespinning chain used on initial make-up cancause galling of the threads).
3. Tong them up to the predetermined torque usinga recently calibrated torque gauge to measurethe required line-pull.Note: Monitor breakout torque. It should be
less than or no greater than make-uptorque. If it is greater, the connectionshould be cleaned, inspected andrepaired, before it is made up again.
4. Breakout, visually inspect, redope and make uptwo more times before running in hole. Alwaysuse backup tongs to make and break connec-tions.
5. Stagger breaks on each trip so that each con-nection can be checked, redoped and made upevery second or third trip, depending on thelength of drill pipe and size of rig.
A new string of drill pipe deserves good surface han-dling equipment and tools. Check slips and masterbushings before damage occurs to the tube. (See theIADC Drilling Manual for correct measurements).
Do not stop the downward movement of the drill stemwith the slips. This can cause crushing or neckingdown of the drill pipe tube. The drill pipe can also bedamaged by allowing the slips to ride the pipe on tripsout of the hole.
Good rig practices will help eliminate time consumingtrips in the future, looking for washouts or fishing fordrill pipe lost in the hole. For more information refer tothe IADC Drilling Manual.
Drill Pipe
2
New Tool JointsTorque Chart Drill Pipe Tool Joint
Note: 1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on Slim Hole (S.H.) tool joints due to special service requirements.
2. Make-up torque values may be lower than those published in API RP7G. The make-up values are lower due to the combined torsional and tensileloads found in service conditions.
Drill Pipe Type Box Pin Make-upSize Conn OD ID Torque(in) (in) (in) (ft-lb)
N.C. 26 (I.F.) 3 3/8 1 3/4 3,900O.H. 3 1/4 1 3/4 3,700O.H. 3 1/8 2 2,600
2 3/8 S.L. H-90 3 1/4 2 2,700W.O. 3 3/8 2 2,400P.A.C. 2 7/8 1 3/8 2,600
2 7/8” S.H. (N.C. 26) 3 3/8 1 3/4 3,900O.H. 3 3/4 2 7/16 3,100O.H. 3 7/8 2 5/32 4,800S.L. H-90 3 7/8 2 7/16 3,800S.L. H-90 3 7/8 2 5/32 6,800
2 7/8 P.A.C. 3 1/8 1 1/2 3,200W.O. 4 1/8 2 7/16 3,900X.H. 4 1/4 1 7/8 7,000N.C. 31 (I.F.) 4 1/8 2 1/8 6,400N.C. 31 (I.F.) 4 1/8 2 7,100N.C. 31 (I.F.) 4 3/8 1 5/8 4,400
3 1/2 S.H. (N.C. 31) 4 1/8 2 1/8 6,400S.L. H-90 4 5/8 3 7,600S.L. H-90 4 5/8 2 11/16 11,110O.H. 4 3/4 3 6,500O.H. 4 3/4 2 11/16 9,300
3 1/2 N.C. 38 (W.O.) 4 3/4 3 6,800N.C. 38 (I.F.) 4 3/4 2 11/16 9,700N.C. 38 (I.F.) 5 2 9/16 10,700N.C. 38 (I.F.) 5 2 7/16 11,700N.C. 38 (I.F.) 5 2 1/8 14,000N.C. 40 (4” F.H.) 5 1/4 2 9/16 14,600N.C. 40 (4” F.H.) 5 3/8 2 7/16 15,600N.C. 40 (4” F.H.) 5 1/2 2 1/4 17,100
S.H. (3 1/2” X.H.) 4 5/8 2 9/16 8,100O.H. 5 1/4 3 15/32 11,900O.H. 5 1/2 3 1/4 14,700N.C. 40 (4” F.H.) 5 1/4 2 13/16 12,400N.C. 40 (4” F.H.) 5 1/4 2 11/16 13,500N.C. 40 (4” F.H.) 5 1/2 2 7/16 15,600N.C. 40 (4” F.H.) 5 1/2 2 7/16 15,600
4 N.C. 46 (W.O.) 5 3/4 3 7/16 15,200N.C. 46 (I.F.) 6 3 1/4 17,600N.C. 46 (I.F.) 6 3 20,500N.C. 46 (I.F.) 6 3 20,500N.C. 46 (I.F.) 6 3 1/4 17,600N.C. 46 (I.F.) 6 3 20,500N.C. 46 (I.F.) 6 2 5/8 24,400N.C. 46 (I.F.) 6 2 7/8 21,900
3
Used Tool JointsTorque Chart Drill Pipe Tool Joint
Box Make-Up Box Make-upOD Torque OD Torque(in) (ft-lb) (in) (ft-lb)
3 1/4 3,000 3 3/16 2,5003 1/16 2,300 3 1/32 2,1003 1,800 2 31/32 1,6002 31/32 2,000 3 31/32 2,0003 1/16 2,000 3 1,5002 25/32 2,500 2 23/32 2,100
3 3/8 4,100 3 5/16 3,6003 1/2 3,300 3 7/16 2,7003 19/32 4,300 3 17/32 3,6003 17/32 3,800 3 17/32 3,8003 19/32 4,600 3 17/32 3,8003 1/8 3,500 3 1/16 3,5003 5/8 3,200 3 9/16 2,5003 23/32 4,400 3 21/32 3,7003 11/16 3,200 3 21/32 2,8003 29/32 5,700 3 13/16 4,6004 1/16 7,700 3 31/32 6,500
4 6,900 3 29/32 5,7004 3/16 5,500 4 1/8 4,5004 3/8 8,800 4 9/32 7,1004 9/32 5,500 4 7/32 4,6004 3/8 7,000 4 5/16 6,0004 3/8 5,300 4 11/32 4,8004 3/8 5,300 4 11/32 4,8004 19/32 8,800 4 1/2 7,3004 21/32 9,900 4 9/16 8,3004 23/32 10,900 4 5/8 9,3004 15/32 11,400 4 13/32 9,0005 12,600 4 7/8 10,2005 3/32 14,400 4 15/16 11,400
4 7/16 8,800 4 11/32 7,4004 31/32 7,500 4 29/32 6,2005 1/32 8,800 4 31/32 7,5004 13/16 9,000 4 23/32 7,3004 15/16 11,400 4 13/16 9,0005 12,600 4 7/8 10,2005 12,600 4 7/8 10,2005 7/32 7,900 5 5/32 6,5005 5/32 10,000 5 7/32 7,9005 7/16 12,800 5 5/16 10,0005 15/32 13,600 5 3/8 11,4005 9/32 9,200 5 3/16 7,2005 9/16 15,800 5 7/16 12,8005 5/8 17,300 5 1/2 14,3005 5/8 17,300 5 1/2 14,300
Note: 3. Make-up torque is based on the use of 40% to 50% by weight of finely pow-dered metallic zinc, applied to all threads and shoulders.
Premium Class 2
4
New Tool JointsTorque Chart Drill Pipe Tool Joint
Drill Pipe Type Box Pin Make-upSize Conn OD ID Torque(in) (in) (in) (ft-lb)
O.H. 5 7/8 3 3/4 14,600F.H. 6 3 17,600F.H. 6 2 3/4 20,100F.H. 6 2 1/2 22,300N.C. 46 (X.H.) 6 1/4 3 1/4 17,600N.C. 46 (X.H.) 6 1/4 3 20,500
4 1/2 N.C. 46 (X.H.) 6 1/4 2 3/4 23,200N.C. 46 (X.H.) 6 1/4 2 1/2 25,600N.C. 50 (I.F.) 6 3/8 3 3/4 19,800N.C. 50 (I.F.) 6 3/8 3 3/4 19,800N.C. 50 (I.F.) 6 3/8 3 5/8 21,600N.C. 50 (I.F.) 6 3/8 3 1/2 23,400N.C. 50 (I.F.) 6 3/8 2 7/8 30,300
N.C. 50 (X.H.) 6 3/8 33/4 19,800N.C. 50 (X.H.) 6 3/8 3 1/2 23,400N.C. 50 (X.H.) 6 1/2 3 1/4 26,800N.C. 50 (X.H.) 6 1/2 3 30,000
5 N.C. 50 (X.H.) 6 5/8 2 3/4 32,9005 1/2” F.H. 7 3 1/2 37,4005 1/2” F.H. 7 1/4 3 1/2 37,4005 1/2” F.H. 7 1/4 3 1/4 41,200
F.H. 7 4 29,200F.H. 7 4 29,200F.H. 7 3 3/4 33,400
5 1/2 F.H. 7 1/4 3 1/2 37,400F.H. 7 1/4 3 1/2 37,400F.H. 7 1/4 3 1/2 37,400F.H. 7 1/2 3 44,600F.H. 7 1/2 3 44,600
F.H. 8 5 38,400F.H. 8 5 38,400F.H. 8 5 38,400
6 5/8 F.H. 8 1/4 4 3/4 44,600F.H. 8 1/4 4 3/4 44,600F.H. 8 1/4 4 3/4 44,600F.H. 8 1/2 4 1/4 56,100F.H. 8 1/2 4 1/4 56,100
Note: 1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on Slim Hole (S.H.) tool joints due to special service requirements.
2. Make-up torque values may be lower than those published in API RP7G. The make-up values are lower due to the combined torsional and tensileloads found in service conditions.
5
Box Make-Up Box Make-upOD Torque OD Torque(in) (ft-lb) (in) (ft-lb)
5 15/32 12,300 5 3/8 10,0005 3/8 12,100 5 9/32 10,1005 9/16 16,400 5 7/16 13,5005 5/8 17,800 5 15/32 14,2005 13/32 12,100 5 5/16 9,9005 19/32 16,500 5 15/32 13,5005 25/32 21,200 5 5/8 17,3005 23/32 19,600 5 9/16 15,8005 29/32 16,600 5 25/32 13,2005 23/32 11,600 5 21/32 10,0005 13/16 14,100 5 23/32 11,6005 15/16 17,500 5 27/32 14,9006 7/32 25,500 6 1/16 21,000
5 7/8 15,800 5 25/32 13,3006 1/32 20,200 5 29/32 16,7006 3/32 21,900 5 31/32 18,4006 3/16 24,700 6 1/32 22,0006 5/16 27,500 6 3/16 22,9006 21/32 25,500 6 1/2 20,2006 23/32 27,700 6 9/16 22,3006 15/16 35,500 6 3/4 28,800
6 17/32 21,300 6 7/16 18,2006 9/16 22,300 6 15/32 19,2006 5/8 24,500 6 1/2 20,3006 23/32 27,650 6 19/32 23,3506 25/32 29,900 6 5/8 24,5006 25/32 29,900 6 11/16 26,5607 1/32 39,000 6 27/32 32,1007 1/32 39,000 6 7/8 33,200
7 7/16 26,800 7 3/8 24,1007 1/2 29,500 7 13/32 25,5007 5/8 35,100 7 1/2 29,5007 11/16 38,000 7 9/16 32,3007 11/16 38,000 7 19/32 33,7007 3/4 40,900 7 21/32 36,5007 29/32 48,200 7 25/32 42,3008 52,700 7 27/64 45,200
Used Tool JointsTorque Chart Drill Pipe Tool Joint
Premium Class 2
Note: 3. Make-up torque is based on the use of 40% to 50% by weight of finely pow-dered metallic zinc, applied to all threads and shoulders.
Performance Properties of Seamless Drill Pipe
6
Cro
ss
Po
lar
Wal
lS
ectio
nal
Sec
tiona
lS
ize
No
min
alT
hic
kA
rea
Mo
du
lus
OD
Wei
gh
tn
ess
IDo
f P
ipe
Z(i
n)
(lb
/ft)
(in
)(i
n)
(sq
. in
)(c
u in
)E
75X
95G
105
S13
5E
75X
95G
105
S13
5
2 3 /
84.
850.
190
1.99
51.
3042
1.32
04,
760
6,02
06,
060
97,8
2012
3,90
013
6,94
017
6,07
06.
650.
280
1.81
51.
8429
1.73
46,
240
7,90
08,
740
138,
220
175,
080
193,
500
248,
790
2 7 /
86.
850.
217
2.44
11.
8120
2.24
28,
070
10,2
2011
,300
135,
900
172,
140
190,
260
244,
620
10.4
00.
362
2.15
12.
8579
3.20
411
,530
14,6
1016
,150
20,7
6021
4,34
027
1,50
030
0,08
038
5,82
03
1 /2
9.50
0.25
42.
992
2.59
023.
922
14,1
2017
,890
19,7
7025
,420
194,
260
246,
070
271,
970
349,
680
13.3
00.
368
2.76
43.
6209
5.14
418
,520
23,4
6025
,930
33,3
3027
1,57
034
3,99
038
0,19
048
8,82
015
.50
0.44
92.
602
4.30
375.
846
21,0
5026
,660
29,4
7037
,890
322,
780
408,
850
451,
890
581,
000
411
.85
0.26
23.
476
3.07
675.
400
19,4
4024
,620
27,2
2034
,990
230,
750
292,
290
323,
050
415,
360
14.0
00.
330
3.34
03.
8048
6.45
823
,250
29,4
5032
,550
41,8
4028
5,36
036
1,46
039
9,50
051
3,65
015
.70
0.38
03.
240
4.32
167.
156
25,7
6032
,630
36,0
7046
,380
324,
150
410,
590
453,
810
583,
420
4 1 /
213
.75
0.27
13.
958
3.60
047.
184
25,8
6032
,760
36,2
1046
,550
270,
030
342,
040
378,
050
486,
060
16.6
00.
337
3.82
64.
4074
8.54
230
,750
38,9
5043
,050
55,3
5033
0,56
041
8,70
046
2,78
059
5,00
020
.00
0.43
03.
640
5.49
8110
.232
36,8
4046
,660
51,5
7066
,300
412,
360
522,
320
577,
300
742,
240
519
.50
0.36
24.
276
5.27
4611
.416
41,0
9052
,050
57,5
3073
,970
395,
600
501,
090
553,
830
712,
070
25.6
00.
500
4.00
07.
0686
14.4
9052
,160
66,0
7073
,030
93,9
0053
0,14
067
1,52
074
2,20
095
4,26
0
5 1 /
221
.90
0.36
14.
778
5.82
8214
.062
50,6
2064
,120
70,8
7091
,120
437,
120
553,
680
611,
960
786,
810
24.7
00.
415
4.67
06.
6296
15.6
8856
,470
71,5
3079
,060
101,
650
497,
220
629,
810
696,
110
895,
000
5 7 /
823
.40
0.36
1 5.
153
6.25
3516
.251
58,6
0074
,200
82
,000
10
5,50
0 46
9,00
0 59
4,10
0 65
6,60
0 84
4,20
026
.30
0.41
55.
045
7.11
8518
.165
65,5
0083
,000
91,7
0011
7,90
053
3,90
067
6,30
074
7,40
096
1,00
0
6 5 /
825
.20
0.33
05.
965
6.52
6219
.572
70,5
5089
,360
98,7
7012
7,04
448
9,46
061
9,99
068
5,25
088
1,04
427
.70
0.36
25.
901
7.12
2621
.156
76,3
0096
,600
106,
800
137,
300
534,
200
676,
700
747,
900
961,
600
Tors
ion
al Y
ield
Str
eng
th (
ft-l
b)
Ten
sile
Yie
ld S
tren
gth
(lb
)
New
Dri
ll P
ipe
Dim
ensi
on
al, T
ors
ion
al, a
nd
Ten
sile
Dat
a
- - --
Siz
eN
om
inal
OD
Wei
gh
t(i
n)
(lb
)
2 3 /
84.
8511
,040
13,9
8015
,460
19,0
7010
,500
13,3
0014
,700
18,9
006.
6515
,600
19,7
6021
,840
28,0
8015
,470
19,6
0021
,660
27,8
502
7 /8
6.85
10,4
7012
,930
14,0
1017
,060
9,91
012
,550
13,8
7017
,830
10.4
016
,510
20,9
1023
,110
29,7
2016
,530
20,9
3023
,140
29,7
503
1 /2
9.50
10,0
4012
,060
13,0
5015
,780
9,52
012
,070
13,3
4017
,150
13.3
014
,110
17,8
8019
,760
25,4
0013
,800
17,4
8019
,320
24,8
4015
.50
16,7
7021
,250
23,4
8030
,190
16,8
4021
,330
23,5
7030
,310
411
.85
8,41
09,
960
10,7
0012
,650
8,60
010
,890
12,0
4015
,480
14.0
011
,350
14,3
8015
,900
20,1
7010
,830
13,7
2015
,160
19,4
9015
.70
12,9
0016
,340
18,0
5023
,210
12,4
7015
,790
17,4
6022
,440
4 1 /
213
.75
7,20
08,
400
8,95
010
,310
7,90
010
,010
11,0
7014
,230
16.6
010
,390
12,7
5013
,820
16,8
009,
830
12,4
5013
,760
17,6
9020
.00
12,9
6016
,420
18,1
5023
,330
12,5
4015
,890
17,5
6022
,580
519
.50
10,0
0012
,010
12,9
9015
,700
9,50
012
,040
13,3
0017
,110
25.6
013
,500
17,1
0018
,900
24,3
0013
,120
16,6
2018
,380
23,6
205
1 /2
21.9
08,
440
10,0
0010
,740
12,7
108,
610
10,9
1012
,060
15,5
1024
.70
10,4
6012
,920
14,0
0017
,050
9,90
012
,540
13,8
6017
,830
5 7 /
823
.40
7,45
08,
770
9,36
010
,820
8,06
010
,220
11,2
9014
,520
26.3
09,
560
11,5
0012
,410
14,8
909,
270
11,7
4012
,980
16,6
90
6 5 /
825
.20
4,81
05,
310
5,49
06,
040
6,54
08,
280
9,15
011
,770
27.7
05,
890
6,75
07,
100
7,81
07,
170
9,08
010
,040
12,9
10
Co
llap
se P
ress
ure
, psi
E75
X95
G10
5S
135
E75
X95
G10
5S
135
Inte
rnal
Pre
ssu
re, p
siNew Drill Pipe Collapse and Internal Pressure Data
7
8
Tool Joint Bevel Diameters
Internal Flush
&Numbered
Connections
Full Hole&
NumberedConnections
Xtra Hole &Numbered
Connections
H-90
SlimlineH-90
Slimhole &
NumberedConnections
2 3/8 & N.C 26 3 3/8 3 17/64
2 7/8 & N.C 31 4 1/8 3 61/64
3 1/2 & N.C 38 4 3/4 4 37/64
3 1/2 & N.C 38 5 4 37/64
N.C. 40 5 1/2 5 1/64
4 & N.C. 46 6 5 23/32
4 & N.C. 46 6 1/4 5 23/32
4 1/2 & N.C. 50 6 1/8 6 1/16
4 1/2 & N.C. 50 6 1/4 6 1/16
4 1/2 & N.C. 50 6 3/8 6 1/16
4 1/2 & N.C. 50 6 1/2 6 1/16
4 1/2 & N.C. 50 6 5/8 6 1/16
N.C. 56 7 6 47/64
3 1/2 4 5/8 4 31/64
4 & N.C. 40 5 1/4 5 1/64
4 1/2 6 5 23/32
5 1/2 7 6 23/32
5 1/2 7 1/4 6 23/32
5 1/2 7 1/2 7 3/32
3 1/2 4 3/4 4 17/32
4 1/2 & N.C. 46 6 5 23/32
5 & N.C. 50 6 1/4 5 59/64
4 5 1/2 5 17/64
4 1/2 6 5 23/32
2 3/8 3 1/4 3 1/8
2 7/8 3 7/8 3 23/32
3 1/2 4 5/8 4 7/16
2 3/8 2 7/8 2 25/32
2 7/8 & N.C. 26 3 3/8 3 17/64
3 1/2 & N.C. 31 4 1/8 3 61/64
4 4 1/2 4 11/32
4 4 5/8 4 11/32
4 1/2 & N.C. 38 5 4 37/64
Type Size OD Bev. Dia
Fraction Decimal mm Fraction Decimal mm
1/64 0.015625 0.397 33/64 0.515625 13.0971/32 0.03125 0.794 17/32 0.53125 13.494
3/64 0.046875 1.191 35/64 0.546875 13.8911/16 0.0625 1.588 9/16 0.5625 14.288
5/64 0.078125 1.984 37/64 0.578125 14.6843/32 0.09375 2.381 19/32 0.59375 15.081
7/64 0.109375 2.778 39/64 0.609375 15.4781/8 0.1250 3.175 5/8 0.6250 15.875
9/64 0.140625 3.572 41/64 0.640625 16.2725/32 0.15625 3.969 21/32 0.65625 16.669
11/64 0.171875 4.366 43/64 0.671875 17.0663/16 0.1875 4.763 11/16 0.6875 17.463
13/64 0.203125 5.159 45/64 0.703125 17.8597/32 0.21875 5.556 23/32 0.71875 18.256
15/64 0.234375 5.953 47/64 0.734375 18.6531/4 0.2500 6.350 3/4 0.7500 19.050
17/64 0.265625 6.747 49/64 0.765625 19.4479/32 0.28125 7.144 25/32 0.78125 19.844
19/64 0.296875 7.541 51/64 0.796875 20.2415/16 0.3125 7.938 13/16 0.8125 20.638
21/64 0.328125 8.334 53/64 0.828125 21.03411/32 0.34375 8.731 27/32 0.84375 21.431
23/64 0.359375 9.128 55/64 0.859375 21.8283/8 0.3750 9.525 7/8 0.8750 22.225
25/64 0.390625 9.922 57/64 0.890625 22.62213/32 0.40625 10.319 29/32 0.90625 23.019
27/64 0.421875 10.716 59/64 0.921875 23.4167/16 0.4375 11.113 15/16 0.9375 23.813
29/64 0.453125 11.509 61/64 0.953125 24.20915/32 0.46875 11.906 31/32 0.96875 24.606
31/64 0.484375 12.303 63/64 0.984375 25.0031/2 0.5000 12.700 1 25.400
9
1.000
Decimal and Millimeter Equivalents
1 mm = 0.03937 inch0.001 inch = 0.0254 mm
10
Basic Customary SI/Metric ConversionUnit Units Units Customary to
(Abbreviation) (Abbreviation) SI/MetricMultiply by
Length in mm 25.4
Area sq in mm2 645.16
Volume, capacity cu ft m3 0.028317U.K. gal L 4.546092U.S. gal L 3.785412
Plane angle deg (0) rad 0.017453
Time min S 60
Mass lbm kg 0.453592
Temperature (traditional) 0F 0C
Pressure lbf/in2(psi) bar 0.068947N/m2 Pa 1.at (kp/cm2) bar 1.0197bar Pa 105
Density (liquids) lbm/U.S. gal kg/m3 119.8264lbm/U.K. gal kg/m3 99.77633lbm/ft kg/m3 16.01846
Density (solids) lbm/ft3 kg/m3 16.01846
Throughput (mass basis) lbm/hr kg/h 0.453592
Throughput (volume basis) bbl/D m3/h 0.006624ft3/D m3/h 0.001179U.K. gal/min L/min 4.546092U.S. gal/min L/min 3.785412
Flow rate (volume basis) U.K. gal/min L/min 4.546092U.S. gal/min L/min 3.785412
ft3/min m3/min 0.028314
Energy work Btu kWh 0.000293ft-lbf kJ 0.001356lbf-ft kJ 0.001356K N-m kJ 1.
Power hydraulic horse kW 0.746043power-hhphp (electric) kW 0.746Btu/hr W 0.293071
Fuel consumption mile/U.S. gal km/L 0.425144mile/U.K. gal km/L 0.354066
Velocity (linear) speed ft/min m/s 0.005080in/s mm/s 25.4
Rotational frequency rev/s rev/s 1.0rev/min rev/s 0.016666
Weight/length lb/ft kg/m 1.488164
Force lbf N 4.448222kg-m/sec2 N 1.
Bending moment torque lbf-ft Nm 1.355818
Section modulus cu in mm3
Stress kgf/mm2 N/mm2 9.806650lbf/in2 (psi) N/mm2 0.006895
(0F-32)
1.8
2831685
Conversion of Customary Units to SI/Metric Units
11
DO
UB
LE
S
HO
UL
DE
RC
ON
NE
CT
ION
S
BoxWeld
Pipe
Pin
External UpsetTool Joint
Elevator ShoulderInternal Upset
Internal Coating
Pin BasePin base extendsin spring-like manner when jointis bucked up torecommendedmake-up torque.
SecondaryShoulderWhen joint is handtight, secondaryshoulders do notcontact. When jointis bucked up torecommendedmake-up torque,they do contact.
Primary ShoulderProvides seal andpreload just ason conventionaltool joint.
Box CounterboreSection Box counterboresection compressesin spring-like mannerwhen joint is buckedup to recommendedmake-up torque.
Grant PridecoDouble Shoulder Connection
Pin Nose
Drill Pipe withDouble Shoulder Connections
Hardbanding
12
Types of Grant Prideco DoubleShoulder Connections
There are three types of double shoulder connectionsoffered by Grant Prideco.
• HI TORQUE® (HT) – First generation double shoul-der connection providing approximately 40% moretorque capacity than API connections of equivalentdimensions. Not interchangeable with API connec-tions.
• eXtreme® Torque (XT® ) – Second generation doubleshoulder connection providing approximately 70%more torque capacity than API connections of equiv-alent dimensions. Not interchangeable with APIconnections. Two primary differences exist betweenHT and XT connections: 1) XT has a flatter taperand 2) XT has increased thread root radii.
o eXtreme® Torque with Metal-To-Metal Seal (XT-M™) – Industry first gas tight pressure rated rotaryshoulder connection achieved through a 15° metal-to-metal (M-T-M) seal on the pin nose. Providestorque capacity similar to that of XT connections.Not interchangeable with API connections.
• Grant Prideco Double Shoulder™ (GPDS™) –Double shoulder connection which is interchange-able with API connections and provides 20-50%more torque capacity than API connections ofequivalent dimensions.
The below figure illustrates the taper difference betweenHT and XT connections.
XT
HT
13
HT Tool Joint Make-up Torque ChartRecommended Maximum
3 3/83 1/83 1/83 1/83 1/43 3/163 1/83 5/83 5/83 5/8 3 1/23 3/84 1/4 4 1/84 1/84 1/84 1/8
4555
4 15/164 7/84 7/84 3/44 3/44 3/45 1/45 1/85 1/8
55
6 1/46 1/46 5/86 5/86 5/86 5/86 1/27 3/87 1/47 1/47 1/47 1/47 1/47 1/47 1/87 1/87 1/8
777778
1.8151 7/161 3/41.9751 1/21 1/21 1/21 1/41 3/81 1/21 1/21 3/41 3/41 7/8
22 1/82 5/322 5/322 5/162 7/162 9/162 9/162 7/162 9/162 7/162 9/162 11/162 13/162 9/162 11/162 7/162 9/16
3 3 1/4
3 3 1/43 1/23 3/43 1/2
43
3 1/43 1/23 3/43 7/8
43 1/43 7/8
43
3 1/43 1/23 3/4
4 5
6,3006,8005,6004,6005,2005,1005,1009,2008,7007,9007,3005,20014,00011,90011,30010,0009,6008,90021,70019,80017,70017,70019,30017,70017,00016,10015,20019,20021,10020,10019,60018,60034,60028,50053,30046,80039,70032,00039,60046,80072,00069,00063,90055,60051,20046,70064,20051,10046,50062,50059,50056,30052,60046,30059,800
2 3/8 HTSLH90
2 7/8 HTPAC
HT26
HT31
HT38
HT40
HT46
HT50
HT55
HT65
TypeConnection
BoxOD(in)
PinID(in)
Make-upTorque(ft-lb)
Note: Applies to drill pipe and HWDP tool joints.
14
XT® Tool Joint Make-upTorque ChartRecommended Maximum
3 1/8 3 1/2 3 1/2 3 1/2 3 3/4 4 1/8 4 1/8
4 4 4 4
4 7/84 13/164 3/44 3/4 4 3/4
5555
4 15/164 15/164 29/324 29/324 7/84 7/84 7/8 4 7/8 5 1/45 1/45 1/4 6 1/46 5/86 5/86 1/26 1/26 1/26 3/86 3/86 3/46 5/87 3/8
77 3/87 1/47 1/47 1/47 1/47 1/47 1/4 7 1/87 1/8
7 7 7 7 8
8 1/2
1 1/2 1 1/4 1 1/21 3/4
21 7/8
22
2 1/8 2 5/322 3/8
2 9/162 9/162 7/162 9/162 11/162 9/162 11/162 13/162 7/8
2 9/162 13/162 3/4
2 13/162 9/162 11/162 3/4
2 13/162 11/162 13/16
3 3 1/4 3 1/23 3/42 3/4 3 1/2 3 3/43 1/23 3/4
44
3 5/84
3 1/4 3 3/16 3 1/43 1/23 3/4
44 1/43 1/44 1/43 1/23 3/4
44 1/4
55 1/4
5,7009,9008,9006,9009,000
14,00012,70012,20011,20010,8007,900
18,90018,80020,50018,80016,60024,50022,20019,80018,60023,40019,80021,00019,80022,20021,20020,70019,80028,80026,40022,40042,10054,40046,40061,60052,80046,20048,70045,10052,00049,90072,20058,10090,00085,70084,90081,90076,30066,90056,90079,90056,80071,60067,90063,70056,60081,200100,300
XT24
XT26
XT29
XT31
XT38
XT39
XT40
XT46
XT50
XT54
XT55
XT57
XT69XT65
TypeConnection
BoxOD(in)
PinID(in)
XT Make-upTorque(ft-lb)
Note: Applies to drill pipe and HWDP tool joints.
15
XT-M™ Tool Joint Make-upTorque ChartRecommended Maximum
3 3/8 4 4
3 7/8 4 1/4 4 3/4 4 3/4
5 5 5
4 7/85 1/45 1/45 1/46 1/4 6 5/86 1/26 1/46 1/47 1/4
778
8 1/2
1 3/4 2
2 1/82 1/8
2 9/162 9/162 11/162 7/162 9/16
2 13/162 11/162 11/16
33 1/4
33 1/23 3/43 1/23 5/84 1/44 1/84 1/4
55 1/4
5,80010,8009,7008,5009,500
16,70014,50023,30022,30017,70018,90026,20023,50019,50045,10050,30042,10040,70038,90051,90056,50051,60074,60092,900
XT-M26
XT-M34
XT-M39
XT-M31
XT-M38
XT-M40
XT-M43
XT-M46
XT-M50
XT-M57
XT-M65XT-M69
TypeConnection
BoxOD(in)
PinID(in)
XT-MMake-upTorque(ft-lb)
Note: Applies to drill pipe and HWDP tool joints.
16
GPDS™ Tool Joint Make-upTorque ChartRecommended Maximum
3 1/23 1/2 3 1/24 1/84 1/8
55
4 7/84 7/84 3/44 3/45 1/45 1/45 1/4
5 5
6 1/2666
6 5/86 5/86 5/86 1/26 1/26 1/26 3/87 1/47 1/47 1/8
7 77
8 1/488
1 3/41 11/161 5/8
21 7/82 7/162 9/162 7/162 9/162 1/82 1/22 7/162 9/162 11/162 7/162 9/16 3 1/22 3/4
3 3 1/42 3/4
3 3 1/43 1/43 1/23 3/43 1/43 3/44 1/83 3/43 1/2 3 3/4
44 3/4
4 15/164 7/8
5,3005,8006,30010,30010,90017,50015,50017,10015,40016,90014,50022,80021,90019,60017,80016,90018,80036,40031,80025,70054,40049,70043,30043,10036,10028,50041,20053,80040,10053,60053,90050,30044,50071,40061,20064,500
GPDS26
GPDS31
GPDS38
GPDS40
GPDS46
GPDS50
GPDS55
GPDS65
TypeConnection
BoxOD(in)
PinID(in)
Make-upTorque(ft-lb)
Note: Applies to drill pipe and HWDP tool joints.
17
Tool Joint Break-inMost drill pipe connections are broken-in during manu-facture. The following break-in procedure is recom-mended for connections which have not been broken-induring manufacture.
Step 1: Make the joints up to the maximum recom-mended make-up torque, and then breakthem out. If the break-out torque is lessthan the make-up torque, the joints do nothave to be separated.
Step 2: Make the joints up again to the samemake-up torque and break them out.Separate the pin and box and reapplythread compound.
Step 3: Make the joints up again to the same make-up torque and they are ready for service.
Note: The break-out torque should be less thanthe make-up torque. If the break-out torqueis more than the make-up torque, separatethe joints and inspect them for damage.
Picking Up Pipe with Double ShoulderConnections for the First Time• Visually examine the thread protectors for damage
such as dents or crushing. If any thread protectors aredamaged, inspect the threads on that joint for dam-age.
• If the joints were shipped to the rig with rust preventiveon the threads, it must be removed. Use soap andwater, steam or a vapor degreasing solvent such asVarsol. No residue should remain on the threads aftercleaning.
• If the joints were shipped to the rig with thread com-pound, it is not necessary to remove the thread com-pound unless there is a problem suspected.
• Inspect the threads for damage or for foreign material.
• Before the joints are put in service, the threads, the pri-mary make-up shoulders and secondary make-upshoulders must be coated with a good quality rotaryshouldered connection thread compound.
The following sections provide general guidelines for runningand handling double shoulder connections. Connection-spe-cific running and handling procedures are available direct fromGrant Prideco and can be downloaded fromwww.grantprideco.com.
18
Special Considerations When RunningXT® and XT-M™ Connections
• Check to ensure the counterbalance on the topdrive is working properly and provides a minimumamount of weight applied to the connection duringmake-up.
• Ensure the bore through the top drive bell stabbingguide (top drive flipper) is no more than 1/2" largerin diameter than the box tool joint diameter.
• Because of the flatter taper, XT and XT-M pins donot stab as deeply into the box as do HT, GPDS™and API connections. Alignment of the pin to thebox when stabbing and spinning up is more criticalfor XT and XT-M connections. A stabbing guide isrequired when running XT and XT-M connections,and alignment should be verified before spinningup.
• Proper alignment, along with slow initial make-up ofthe starting threads, is necessary with XT and XT-Mconnections. Use chain tongs or slow speed spin-ners when spinning in the starting threads. High-speed spinners may be used after the startingthreads are engaged.
• Minor thread damage may occur within the startingthreads. This is not detrimental to the connectionand should be removed with a soft grinding wheelor a file.
19
Application of Thread Compound toDouble Shoulder Connections
• All contacting surfaces, the threads, the primaryshoulders, secondary shoulders and 15° M-T-M seal(XT-M™), must be coated with a good quality rotaryshoulder connection thread compound. Copper-based thread compounds are recommended.
• Some drilling fluids or drilling fluid additives mayaffect the frictional properties of the tool joint andthread compound. If this is the case, rinse the drillingfluid off the connections before applying thread com-pound.
• Remove drilling fluid from the secondary shoulderand 15° M-T-M seal (XT-M) of the box before makingup the connection for the trip in the hole. Trappeddrilling fluid can promote corrosion of the secondaryshoulders.
• Racking the pipe will wipe thread compound off thepin nose. If pins are doped coming out of the hole,reapply compound to the secondary shoulder beforethe connections are made up.
• NOTE: For XT-M connections, localized corrosion or pittingmay occur on the 15° M-T-M seal if racked back withoutthread compound applied to it. This is more common withcompletion fluids than common drilling fluids. Apply a liber-al and even coat of quality thread compound to the 15° sealwhen racking back XT-M connections.
PrimaryShoulder
Threads
SecondaryShoulder
15° M-T-MSeal
20
Tonging, Proper Gripping of the BoxDuring Make-up
• Tongs should be placed at least 2 inches from themake-up shoulder on XT® boxes size 46 and greater,all HT and all XT-M™ boxes. These are considered"long" double shoulder connections. This is notrequired for XT boxes less than 46 and all GPDS™boxes.
• The threads of a long double shoulder box are about1-1/2 inches further away from the makeup shoulderthan the threads of an API box. Tongs or top drivetorque wrenches should engage these long doubleshoulder boxes at the same location in relation to thethreads that they would engage an API joint.
• On the Varco BJ® PH85 pipe handler torque wrench,this can be accomplished by decreasing the length ofthe saver sub from 7 inches to 5-1/2 inches. This willput the tong dies 2 inches from the box make-upshoulder.
• Back-up tongs should always be used
2 inches
RecommendedTonging Area
21
Tong Height
• Bucking up tool joints with tongs can put high bend-ing loads in the pipe.
• Review Section B4, Paragraph B of the IADCDrilling Manual, or Figure 35 of API RP7G aboutheight of tool joint above slips to prevent bendingpipe during tonging.
H max
P
P
22
Alignment when Making upConnections
• Galling and other damage can occur during stab-bing and spinning connections up.
• A stand of pipe can weigh between 1,500 lbs and2,300 lbs. At initial contact, the weight could be supported by the sharp edge of one thread againstthe flank of the mating thread. This can cause highcontact stresses and wipe the thread compound off.
• Slight misalignment of the pin and box can cause further increases in the stresses when spinning up.
• The “whipping” action of spinning pipe can causehigh loads on threads.
• NOTE: Alignment of the pin to the box when stab-bing and spinning up is more critical for XT® andXT-M™ connections. A stabbing guide is requiredwhen running XT and XT-M connections and align-ment should be verified before spinning up.
Box
Pin
Contact of sharp edge ofpin thread on box flank
Tripping
• Alternate breaks when tripping so that each jointwill 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 ofdownhole make-up or thread damage.
• Do not let the end of the pin strike the box make-upshoulder when stabbing the pin in the box.Stabbing guides are required for XT and XT-M con-nections and recommended for HT and GPDS™connections.
23
Standing Pipe Back
• Using normal drill pipe care and handling practices,no special care is required to protect the pin nosewhen standing the pipe back. The pin nose is not aseal. Minor damage to the pin nose from standingthe pipe back does not affect the connection’s per-formance.
• It is not necessary to use thread protectors whenstanding the pipe back.
• Do not use pressed steel thread protectors whenstanding the pipe back. They could allow theweight of the stand to be supported by the primarymake-up shoulder of the connection on the sharpedge of the thread protectors.
• Apply a liberal and even coat of quality thread com-pound to the 15° M-T-M seal when racking backXT-M™ connections.
Sharp edge of thread protectorcan damageshoulder.
24
Downhole Make-up
• Downhole make-up can be detected by high break-out torque. The break-out torque should be less thanthe make-up torque.
• If downhole make-up is suspected, punch mark thepin and box next to the make-up shoulders when trip-ping into the hole (after the connection is made up).
• If downhole make-up occurs, the position of thepunch marks will change.
• Downhole make-up can cause
— Compressed box counterbores
— Compressed pin noses
Milled Hardness Flat
Punch marks
Apply punch marks in linewith hardness flat to makethem easier to find.
25
Make-up Shoulder and Bevel Diameter
• The primary make-up shoulders provide the seal forthe connection (HT, XT® and GPDS™). For XT-M™,the primary seal is the 15° M-T-M seal and the back-up seal is the primary make-up shoulder.
• The primary make-up shoulders and 15° M-T-M seal(XT-M) should be inspected frequently using currentGrant Prideco Field Inspection Procedures for theapplicable connection type.
• Proper operation and correct shoulder loads dependon the pin length and box depth of double shoulderconnections being within specifications. The pinlength and box depth are shown on the FieldInspection Drawing for the particular size and typeconnection.
• No more than 1/32 inch should be removed fromeither the primary or secondary make-up shoulder atany one refacing. No more than 1/16 inch cumula-tively should be removed from either the primary orsecondary make-up shoulder. The correct pin lengthand box depth must be maintained when resurfacingmake-up shoulders.
• The Grant Prideco benchmark is a reference forchecking how much material has been removedfrom make-up shoulders.
• The surface finish of the primary make-up shouldershould be 150 RMS or less.
• When Grant Prideco double shoulder connectionsare refaced, the bevel does not need to be rema-chined.
The following sections provide information and general guide-lines regarding the field inspection of Grant Prideco doubleshoulder connections and are not intended to replace GrantPrideco Field Inspection Procedures and Drawings.
Connection type-specific Field Inspection Procedures andconnection type and size-specific Field Inspection Drawingsare available direct from Grant Prideco and can be down-loaded from www.grantprideco.com.
26
Pin
1 2 3
1 2 3
1 2 3
1 2 3
• The pin nose is not a seal, it is a mechanical stop.The pin nose must be free of raised metal or otherimperfections that could prevent proper make up orcause galling. Pin nose damage can be repairedwith a hand file.
Box
27
Checking Pin Length
• The pin length can be checked with a dial indicatoror depth micrometers. If the pin length is short by1/32 inch or less, the pin can be repaired by resur-facing the primary shoulder.
• If the pin length is short by more than 1/32 inch, thepin must be recut.
• If the pin length is too long by 1/32 inch or less, thepin can be repaired by resurfacing the pin nose.
• If the pin length is too long by more than1/32 inch,the pin must be recut.
A Go/No Go gauge can be provided by Grant Prideco tofield check double shoulder connections’ primary shoul-der to secondary shoulder pin length and box depth. Thegauge does not provide dimensional information on thepin length or box depth.
If the pin nose does not contact the gauge when usedas shown in the figure, the length should be inspectedwith measuring instruments that determine the actualdistance between the shoulders.
28
Checking Box Depth• The box depth can be checked with a dial indicator
or depth micrometers. If the box depth is short by1/32 inch or less, the box can be repaired by resur-facing the secondary shoulder.
• If the box depth is short by more than 1/32 inch, thebox must be recut.
• If the box depth is too long by 1/32 inch or less, thebox can be repaired by resurfacing the primaryshoulder.
• If the box depth is too long by more than 1/32 inch,the box must be recut.
If the primary shoulder does not contact the gaugewhen used as shown in the figure, the depth should beinspected with measuring instruments that determinethe actual distance between the shoulders.
A Go/No Go gauge can be provided by Grant Prideco tofield check double shoulder connections’ primary shoul-der to secondary shoulder pin length and box depth. Thegauge does not provide dimensional information on thepin length or box depth.
29
Special Considerations WhenInspecting XT® and XT-M™Connections• The stab flank to crest radius of the starting four to
five threads of the pin and box connections round offduring break-in and normal operation. Minor threaddamage may occur within these starting threads.This is not detrimental to the connection and shouldbe removed with a soft grinding wheel or a file.
• The XT-M connection contains a 15° M-T-M seal nearthe pin and box secondary shoulders. This is the pri-mary sealing surface for the connection.
o Round pit type defects up to 1/32 inch indiameter and not exceeding 1/32 inch indepth are permissible.
o Multiple pits of this type are acceptable provided there is at least 1 inch circumferential separation between them.
o Circumferential lines or marks are acceptable provided they cannot be detected by rubbing a fingernail across thesurface.
o Areas highlighted in the figure below are the non-contacting areas of the seal. Damageor pitting is permitted in these areas of theseal, provided the balance of the contact surface is without damage exceeding the requirements above.
o XT-M connections may not be refaced.Damages exceeding requirements for the threads, seal and/or shoulder faces requirethe connection to be faced/chased.
Box Seal
Pin Seal
0.188
0.060
0.060
30
Field Inspection Drawing, Pin
Bev
elD
iaN
ose
Dia
Pin
Cyl
inde
rD
ia
Th
read
Fo
rm
Pin
Leng
th
31
HT Field Inspection Dimensions, Pin
2 3/
8 H
TS
LH90
2 7/
8 H
TP
AC
HT
26H
T31
HT
38H
T40
HT
46H
T50
HT
55H
T65
90°V
084
V 0
76S
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
50V
050
4.42
9 -
4.43
84.
821
- 4.
830
5.15
6 -
5.16
55.
334
- 5.
343
5.49
6 -
5.50
56.
267
- 6.
276
6.28
2 -
6.29
16.
150
- 6.
159
7.33
8 -
7.34
77.
491
- 7.
500
2.98
4 -
3.14
13.
047
- 3.
204
3.29
6 -
3.45
33.
937
- 4.
094
4.63
7 -
4.79
44.
859
- 5.
016
5.82
9 -
5.98
66.
124
- 6.
281
6.85
7 -
7.01
47.
547
- 7.
704
2.60
7 -
2.65
32.
406
- 2.
452
2.71
9 -
2.76
53.
360
- 3.
406
3.88
0 -
3.92
64.
125
- 4.
171
4.67
8 -
4.72
45.
094
- 5.
140
5.68
9 -
5.73
56.
616
- 6.
662
2.21
6 -
2.26
31.
967
- 2.
014
2.10
9 -
2.15
62.
574
- 2.
621
3.17
2 -
3.21
93.
306
- 3.
353
3.85
9 -
3.90
64.
297
- 4.
344
4.66
6 -
4.71
35.
566
- 5.
613
Co
nn
ecti
on
Th
read
Fo
rm
Pin
Len
gth
(in
)
Bev
elD
ia(i
n)
Pin
Cyl
ind
erD
ia(i
n)
No
seD
ia(i
n)
32
XT® Field Inspection Dimensions, Pin
XT
24X
T26
XT
29X
T30
XT
31X
T34
XT
38X
T39
XT
40X
T43
XT
46X
T50
XT
54X
T55
XT
57X
T61
XT
65X
T69
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
3.21
0 -
3.21
93.
116
- 3.
125
3.64
7 -
3.65
63.
366
- 3.
375
3.99
1 -
4.00
04.
147
- 4.
156
4.61
6 -
4.62
54.
491
- 4.
500
4.49
1 -
4.50
03.
647
- 3.
656
7.49
1 -
7.50
07.
291
- 7.
300
6.99
1 -
7.00
07.
241
- 7.
250
7.24
1 -
7.25
06.
241
- 6.
250
8.24
1 -
8.25
07.
804
- 7.
813
2.98
4 -
3.14
13.
203
- 3.
360
3.57
8 -
3.73
53.
703
- 3.
860
3.85
9 -
4.01
64.
109
- 4.
266
4.54
7 -
4.70
44.
770
- 4.
927
5.00
0 -
5.15
75.
047
- 5.
204
5.91
8 -
6.07
56.
302
- 6.
459
6.45
3 -
6.61
06.
857
- 7.
014
6.70
5 -
6.86
26.
961
- 7.
118
7.70
3 -
7.86
07.
797
- 7.
954
2.49
0 -
2.53
62.
728
- 2.
774
3.02
9 -
3.07
53.
174
- 3.
220
3.23
5 -
3.28
13.
535
- 3.
581
3.84
4 -
3.89
04.
026
- 4.
072
4.23
4 -
4.28
04.
385
- 4.
431
4.92
0 -
4.96
65.
306
- 5.
352
5.56
4 -
5.61
05.
680
- 5.
726
5.80
6 -
5.85
26.
213
- 6.
259
6.68
1 -
6.72
77.
056
- 7.
102
2.06
7 -
2.11
42.
309
- 2.
356
2.58
9 -
2.63
62.
740
- 2.
787
2.74
0 -
2.78
73.
063
- 3.
110
3.33
2 -
3.37
83.
531
- 3.
578
3.73
5 -
3.78
23.
927
- 3.
974
4.32
1 -
4.36
84.
743
- 4.
790
5.02
0 -
5.06
75.
101
- 5.
148
5.26
2 -
5.30
95.
530
- 5.
577
6.07
4 -
6.12
16.
476
- 6.
523
Co
nn
ecti
on
Th
read
Fo
rm
Pin
Len
gth
(in
)
Bev
elD
ia(i
n)
Pin
Cyl
ind
erD
ia(i
n)
No
seD
ia(i
n)
33
XT-M™ Field Inspection Dimensions, Pin
XT-
M24
XT-
M26
XT-
M29
XT-
M31
XT-
M34
XT-
M38
XT-
M39
XT-
M40
XT-
M43
XT-
M46
XT-
M50
XT-
M57
XT-
M61
XT-
M65
XT-
M69
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
5.05
4 -
5.06
34.
991
- 5.
000
5.49
1 -
5.50
05.
866
- 5.
875
5.99
1 -
6.00
06.
491
- 6.
500
6.24
1 -
6.25
06.
491
- 6.
500
5.61
6 -
5.62
57.
491
- 7.
500
7.29
1 -
7.30
07.
241
- 7.
250
6.24
1 -
6.25
08.
241
- 8.
250
7.80
4 -
7.81
3
2.98
4 -
3.14
13.
203
- 3.
360
3.57
8 -
3.73
53.
859
- 4.
016
4.07
8 -
4.23
54.
547
- 4.
704
4.77
0 -
4.92
75.
000
- 5.
157
5.04
7 -
5.20
45.
918
-6.
075
6.30
2 -
6.45
96.
705
- 6.
862
6.96
1 -
7.11
87.
703
- 7.
860
7.79
7 -
7.95
4
2.49
0 -
2.53
62.
728
- 2.
774
3.02
9 -
3.07
53.
235
- 3.
281
3.53
5 -
3.58
13.
844
- 3.
890
4.02
6 -
4.07
24.
234
- 4.
280
4.38
5 -
4.43
14.
920
-4.
966
5.30
6 -
5.35
25.
806
- 5.
852
6.21
3 -
6.25
96.
681
- 6.
727
7.05
6 -
7.10
2
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
Co
nn
ecti
on
Th
read
Fo
rm
Pin
Len
gth
(in
)
Bev
elD
ia(i
n)
Pin
Cyl
ind
erD
ia(i
n)
No
seD
ia(i
n)
34
GPDS™ Field Inspection Dimensions, Pin
GP
DS
26G
PD
S31
GP
DS
38G
PD
S40
GP
DS
46G
PD
S50
GP
DS
55G
PD
S65
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
50V
050
3.37
2 -
3.38
23.
884
- 3.
894
4.39
6 -
4.40
64.
907
- 4.
918
4.90
7 -
4.91
84.
907
- 4.
918
5.41
9 -
5.43
05.
419
-5.
430
3.25
0 -
3.40
73.
937
- 4.
094
4.56
2 -
4.71
95.
000
- 5.
157
5.70
3 -
5.86
06.
047
- 6.
204
6.70
3 -
6.86
07.
687
- 7.
844
2.71
9 -
2.76
53.
235
- 3.
281
3.86
0 -
3.90
64.
125
- 4.
171
4.67
8 -
4.72
45.
104
- 5.
150
5.68
8 -
5.73
46.
616
- 6.
620
1.98
5 -
2.03
12.
423
- 2.
469
2.95
4 -
3.00
03.
141
- 3.
187
3.68
8 -
3.73
44.
110
- 4.
156
4.54
8 -
4.59
45.
469
- 5.
515
Co
nn
ecti
on
Th
read
Fo
rm
Pin
Len
gth
(in
)
Bev
elD
ia(i
n)
Pin
Cyl
ind
erD
ia(i
n)
No
seD
ia(i
n)
35
Field Inspection Drawing, Box
Bev
elD
iaC
Bor
eD
ia
C B
ore
Wal
l
Box
Dep
th
36
HT Field Inspection Dimensions, Box
2 3/
8 H
TS
LH90
2 7/
8 H
TP
AC
HT
26H
T31
HT
38H
T40
HT
46H
T50
HT
55H
T65
90°V
084
V 0
76S
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
50V
050
4.44
3 -
4.44
84.
835
- 4.
840
5.16
8 -
5.17
35.
351
- 5.
356
5.51
0 -
5.51
56.
281
- 6.
286
6.29
6 -
6.30
16.
164
- 6.
169
7.35
2 -
7.35
77.
504
- 7.
509
2.98
4 -
3.14
13.
047
- 3.
204
3.29
6 -
3.45
33.
937
- 4.
094
4.63
7 -
4.79
44.
859
- 5.
016
5.82
9 -
5.98
66.
124
- 6.
281
6.85
7 -
7.01
47.
547
- 7.
704
2.72
7 -
2.78
92.
539
- 2.
601
2.90
7 -
2.96
93.
422
- 3.
484
4.04
7 -
4.10
94.
313
- 4.
375
4.87
5 -
4.93
75.
282
- 5.
344
5.87
5 -
5.93
76.
813
- 6.
875
0.09
40.
188
0.18
80.
188
0.31
30.
313
0.31
30.
313
0.31
30.
313
Co
nn
ecti
on
Th
read
Fo
rm
Bo
xD
epth
(in
)
Bev
elD
ia(i
n)
Co
un
ter
bo
reD
ia(i
n)
Min
imu
mC
Bo
re W
all
(in
)
37
XT® Field Inspection Dimensions, Box
XT
24X
T26
XT
29X
T30
XT
31X
T34
XT
38X
T39
XT
40X
T43
XT
46X
T50
XT
54X
T55
XT
57X
T61
XT
65X
T69
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
3.21
7 -
3.22
23.
123
- 3.
128
3.65
4 -
3.65
93.
373
- 3.
378
3.99
8 -
4.00
34.
154
- 4.
159
4.62
3 -
4.62
84.
498
- 4.
503
4.49
8 -
4.50
33.
654
- 3.
659
7.50
5 -
7.51
07.
305
- 7.
310
7.00
5 -
7.01
07.
255
- 7.
260
7.25
5 -
7.26
06.
255
- 6.
260
8.25
5 -
8.26
07.
818
- 7.
823
2.98
4 -
3.14
13.
203
- 3.
360
3.57
8 -
3.73
53.
703
- 3.
860
3.85
9 -
4.01
64.
109
- 4.
266
4.54
7 -
4.70
44.
770
- 4.
927
5.00
0 -
5.15
75.
047
- 5.
204
5.91
8 -
6.07
56.
302
- 6.
459
6.45
3 -
6.61
06.
857
- 7.
014
6.70
5 -
6.86
26.
961
- 7.
118
7.70
3 -
7.86
07.
767
- 7.
954
2.59
3 -
2.65
52.
831
- 2.
893
3.13
2 -
3.19
43.
267
- 3.
329
3.34
2 -
3.40
43.
638
- 3.
700
3.94
7 -
4.00
94.
121
- 4.
183
4.32
4 -
4.38
64.
488
- 4.
550
5.07
1 -
5.13
35.
409
- 5.
471
5.66
7 -
5.72
95.
783
- 5.
845
5.90
9 -
5.97
16.
316
- 6.
378
6.78
4 -
6.84
67.
159
- 7.
221
0.18
80.
188
0.18
80.
188
0.18
80.
188
0.25
00.
250
0.25
00.
313
0.31
30.
313
0.31
30.
313
0.31
30.
313
0.31
30.
313
Co
nn
ecti
on
Th
read
Fo
rm
Bo
xD
epth
(in
)
Bev
elD
ia(i
n)
Co
un
ter
bo
reD
ia(i
n)
Min
imu
mC
Bo
re W
all
(in
)
38
XT-M™ Field Inspection Dimensions, Box
XT-
M24
XT-
M26
XT-
M29
XT-
M31
XT-
M34
XT-
M38
XT-
M39
XT-
M40
XT-
M43
XT-
M46
XT-
M50
XT-
M57
XT-
M61
XT-
M65
XT-
M69
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
V 0
42R
5.06
8 -
5.07
35.
005
- 5.
010
5.50
5 -
5.51
05.
880
- 5.
885
6.00
5 -
6.01
06.
505
- 6.
510
6.25
5 -
6.26
06.
505
- 6.
510
5.63
0 -
5.63
57.
505
- 7.
510
7.30
5 -
7.31
07.
255
- 7.
260
6.25
5 -
6.26
08.
255
- 8.
260
7.81
8 -
7.82
3
2.98
4 -
3.14
13.
203
- 3.
360
3.57
8 -
3.73
53.
859
- 4.
016
4.07
8 -
4.23
54.
547
- 4.
704
4.77
0 -
4.92
75.
000
- 5.
157
5.04
7 -
5.20
45.
918
-6.
075
6.30
2 -
6.45
96.
705
- 6.
862
6.96
1 -
7.11
87.
703
- 7.
860
7.79
7 -
7.95
4
2.59
3 -
2.65
52.
831
- 2.
893
3.13
2 -
3.19
43.
342
- 3.
404
3.63
8 -
3.70
03.
947
- 4.
009
4.12
9 -
4.19
14.
324
- 4.
386
4.48
8 -
4.55
05.
071
-5.
133
5.40
9 -
5.47
15.
909
- 5.
971
6.31
6 -
6.37
86.
784
- 6.
846
7.15
9 -
7.22
1
0.18
80.
188
0.18
80.
188
0.25
00.
250
0.25
00.
250
0.31
30.
313
0.31
30.
313
0.31
30.
313
0.31
3
Co
nn
ecti
on
Th
read
Fo
rm
Bo
xD
epth
(in
)
Bev
elD
ia(i
n)
Co
un
ter
bo
reD
ia(i
n)
Min
imu
mC
Bo
re W
all
(in
)
39
GPDS™ Field Inspection Dimensions, Box
GP
DS
26G
PD
S31
GP
DS
38G
PD
S40
GP
DS
46G
PD
S50
GP
DS
55G
PD
S65
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
38R
V 0
50V
050
3.38
0 -
3.39
13.
892
- 3.
903
4.40
4 -
4.41
54.
915
- 4.
927
4.91
5 -
4.92
74.
915
- 4.
927
5.42
7 -
5.43
95.
427
-5.
439
3.25
0 -
3.40
73.
937
- 4.
094
4.56
2 -
4.71
95.
000
- 5.
157
5.70
3 -
5.86
06.
047
- 6.
204
6.70
3 -
6.86
07.
687
- 7.
844
2.89
9 -
2.96
13.
414
- 3.
476
4.03
9 -
4.10
14.
305
- 4.
367
4.86
7 -
4.92
95.
274
- 5.
336
5.86
7 -
5.92
96.
805
- 6.
867
0.18
80.
188
0.25
00.
250
0.31
30.
313
0.31
30.
313
Co
nn
ecti
on
Th
read
Fo
rm
Bo
xD
epth
(in
)
Bev
elD
ia(i
n)
Co
un
ter
bo
reD
ia(i
n)
Min
imu
mC
Bo
re W
all
(in
)
40
41
HE
AV
YW
EIG
HT
DR
ILL
PIP
E
Heavy weight drill pipe (HWDP) was developed to provide agradual transition from heavy drill collars to relatively light-weight drill pipe. By providing a gradual change in weight andrigidity, HWDP reduces connection fatigue problems andincreases drill stem service life. And because it bends moreeasily than drill collars, it simplifies directional control in high-angle and horizontal drilling. HWDP has less wall contactthan drill collars, reducing differential sticking tendencies.Spiraled HWDP configurations further decrease differentialsticking tendency while helping to remove cuttings out of theannulus. Grant Prideco offers three types of HWDP configu-rations to meet the challenge of severe drilling conditions.
· Conventional HWDP – Developed to provide a grad-ual transition from the heavy drill collar to the relativelylightweight drill pipe.
Heavy Weight Drill Pipe
24”DTool Joint OD
BUpset Diameter
ANominal Size
CWear Section
UpsetDiameter
BElevator Upset
Diameter
180
180
31’NominalLength
24”
26”
Conventional Heavy Weight Drill Pipe
42
· Tri-Spiral™ HWDP – Developed for high-angle applica-tions 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.
Heavy Weight Drill Pipe
24”
B Upset Diameter
A Nominal Size
CSpiral Upset
DBox Tool
Joint
31’NominalLength
24”
Tri-Spiral Heavy Weight Drill Pipe
BElevator Upset
Diameter
D Pin Tool
Joint
26”
26”CSpiral Upset
CCenter
Spiral Upset
26”
43
Heavy Weight Drill Pipe
· Spiral-Wate® HWDP – Designed to handle maximumstress to save time and reduce drilling costs, especiallyin 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.
ANominal
Size
DPin Tool
Joint
CSpiralUpset
BElevator Upset
Diameter
DBox Tool
Joint24”
42”
21’4”
24”
11”
31’NominalLength
Spiral-Wate Heavy Weight Drill Pipe
44
Dimensional Data - Range II
SU
pse
tU
pse
tN
om
inal
Wal
lS
ecti
on
Dia
.D
ia.
Ten
sile
Tors
ion
alC
on
nec
tio
nO
DTe
nsi
leTo
rsio
nal
Per
Mak
e-u
pS
ize
IDTh
ickn
ess
Are
aM
od
ulu
s[C
][B
]Y
ield
Yie
ldS
ize
and
[D]
IDY
ield
Yie
ldP
erJo
int
Torq
ue
(in
)(i
n)
(in
)(i
n2 )
(in
3 )(i
n)
(in
)(l
b)
(ft-
lb)
Typ
e(i
n)
(in
)(l
b)
(ft-
lb)
foo
t(3
1 ft
)(f
t-lb
)
2 7 /
81
1 /2
0.68
84.
727
2.16
13
5 /16
2 15
/ 16
520,
000
22,4
00N
C26
(2
3 /8
IF)
3 3 /
81
1 /2
357,
700
6,30
017
.26
535
3,80
0
3 1 /
22
1 /16
0.71
96.
282
3.70
24
3 7 /
834
5,40
019
,600
NC
38 (
3 1 /
2IF
)4
3 /4
2 1 /
884
2,40
019
,200
25.6
579
511
,500
NC
38 (
3 1 /
2IF
)4
3 /4
790,
900
19,2
0023
.48
728
11,5
003
1 /2
2 1 /
40.
625
5.64
53.
490
43
7 /8
310,
500
18,5
00H
T38
4
7 /8
2 1 /
479
0,90
034
,200
23.9
674
320
,500
XT
394
7 /8
871,
400
40,7
0023
.96
743
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 F
H)
5 1 /
42
9 /16
838,
300
27,8
0029
.92
928
14,6
00X
T39
4 7 /
872
9,70
037
,000
28.4
088
022
,200
4 1 /
22
3 /4
0.87
59.
965
7.69
85
4 11
/ 16
548,
100
40,7
00N
C46
(4
IF)
6 1 /
42
13/ 1
61,
151,
100
43,6
0041
.45
1,28
522
,500
53
1.00
012
.566
10.6
815
1 /2
5 1 /
869
1,20
056
,500
NC
50 (
4 1 /
2IF
)6
5 /8
31,
416,
200
57,8
0050
.38
1,56
230
,000
HT
5088
,800
53,3
00
5 1 /
23
1 /4
1.12
515
.463
14.3
426
5 11
/ 16
850,
400
75,9
005
1 /2
FH
7 1 /
43
1 /4
1,77
8,30
078
,700
61.6
31,
911
41,2
00H
T55
115,
100
69,0
00
5 7 /
84
0.93
814
.542
15.6
306
3 /8
679
9,80
082
,700
XT
577
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 5 /
161,
021,
600
118,
900
6 5 /
8 F
H8
4 1 /
21,
896,
100
87,9
0071
.43
2,21
450
,500
Co
nve
nti
on
al H
eavy
Wei
gh
t D
rill
Pip
e
Tub
eTo
ol J
oin
tW
eig
ht
(lb
)
No
min
al T
ub
eD
imen
sio
ns
Mec
han
ical
P
rop
erti
es T
ub
eM
ech
anic
al
Pro
per
ties
To
ol J
oin
t
Ap
pro
x.
Incl
. Tu
be
&
Too
l Jo
ints
NO
TE
:2
7/8”
HW
DP
is m
anuf
actu
red
inte
gral
onl
y (n
on-w
elde
d).
Cen
.E
nd
45
SU
pse
tU
pse
tN
om
inal
Wal
lS
ecti
on
Dia
.D
ia.
Ten
sile
Tors
ion
alC
on
nec
tio
nO
DTe
nsi
leTo
rsio
nal
Per
Mak
e-u
pS
ize
IDTh
ickn
ess
Are
aM
od
ulu
s[C
][B
]Y
ield
Yie
ldS
ize
and
[D]
IDY
ield
Yie
ldP
erJo
int
Torq
ue
(in
)(i
n)
(in
)(i
n2 )
(in
3 )(i
n)
(in
)(l
b)
(ft-
lb)
Typ
e(i
n)
(in
)(l
b)
(ft-
lb)
foo
t(3
1 ft
)(f
t-lb
)
2 7 /
81
1 /2
0.68
84.
727
2.16
13
5 /16
2 15
/ 16
520,
000
22,4
00N
C26
(2
3 /8
IF)
3 3 /
81
1 /2
357,
700
6,30
018
.22
565
3,80
0
3 1 /
22
1 /16
0.71
96.
282
3.70
24
3 7 /
834
5,40
019
,580
NC
38 (
3 1 /
2IF
)4
3 /4
2 1 /
884
2,40
019
,200
27.0
583
911
,500
NC
38 (
3 1 /
2IF
)4
3 /4
790,
900
19,2
0024
.88
771
11,5
003
1 /2
2 1 /
40.
625
5.64
53.
490
43
7 /8
310,
500
18,5
00H
T38
4
7 /8
2 1 /
479
0,90
034
,200
25.3
678
620
,500
XT
394
7 /8
871,
400
40,7
0025
.36
786
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 F
H)
5 1 /
42
9 /16
838,
300
27,8
0031
.51
977
14,6
00X
T39
4 7 /
872
9,70
037
,000
29.9
993
022
,200
4 1 /
22
3 /4
0.87
59.
965
7.69
85
4 11
/ 16
548,
100
40,7
00N
C46
(4
IF)
6 1 /
42
13/ 1
61,
151,
100
43,6
0043
.31
1,34
322
,500
53
1.00
012
.566
10.6
815
1 /2
5 1 /
869
1,20
056
,500
NC
50 (
4 1 /
2IF
)6
5 /8
31,
416,
200
57,8
0052
.34
1,62
330
,000
HT
5088
,800
53,3
00
5 1 /
23
1 /4
1.12
515
.463
14.3
426
5 11
/ 16
850,
400
75,9
005
1 /2
FH
7 1 /
43
1 /4
1,77
8,30
078
,700
63.7
81,
977
41,2
00H
T55
115,
100
69,0
00
5 7 /
84
0.93
814
.542
15.6
306
3 /8
679
9,80
082
,700
XT
577
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 5 /
161,
021,
600
118,
900
6 5 /
8 F
H8
4 1 /
21,
896,
100
87,9
0074
.67
2,31
550
,500
Tri-
Sp
iral
TM
Hea
vy W
eig
ht
Dri
ll P
ipe
Tub
eTo
ol J
oin
tW
eig
ht
(lb
)
No
min
al T
ub
eD
imen
sio
ns
Mec
han
ical
P
rop
erti
es T
ub
e
Mec
han
ical
P
rop
erti
es
Too
l Jo
int
Ap
pro
x.
Incl
. Tu
be
&
Too
l Jo
ints
Dimensional Data - Range II
NO
TE
:2
7/8”
Tri-
Spi
ralT
Mis
man
ufac
ture
d in
tegr
al o
nly
(non
-wel
ded)
.
Cen
.E
nd
46
SU
pse
tU
pse
tN
om
inal
Wal
lS
ecti
on
Dia
.D
ia.
Ten
sile
Tors
ion
alC
on
nec
tio
nO
DTe
nsi
leTo
rsio
nal
Per
Mak
e-u
pS
ize
IDTh
ickn
ess
Are
aM
od
ulu
s[C
][B
]Y
ield
Yie
ldS
ize
and
[D]
IDY
ield
Yie
ldP
erJo
int
Torq
ue
(in
)(i
n)
(in
)(i
n2 )
(in
3 )(i
n)
(in
)(l
b)
(ft-
lb)
Typ
e(i
n)
(in
)(l
b)
(ft-
lb)
foo
t(3
1 ft
)(f
t-lb
)
3 3 /
162
0.59
44.
840
2.68
73
5 /16
3 3 /
1653
2,40
028
,400
SLH
903
7 /8
2 40
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 /
2IF
)79
0,90
022
,900
13,1
00H
T38
4 7 /
82
1 /4
790,
900
34,2
0030
.39
942
20,5
00X
T39
871,
400
40,7
0024
,400
42
9 /16
0.71
97.
411
5.22
54
1 /2
4 1 /
840
7,60
027
,600
NC
40 (
4 F
H)
5 2
9 /16
838,
300
20,9
0028
.90
896
12,6
00X
T39
72
9,70
040
,800
24,5
00
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 /4
2 13
/ 16
1,15
1,10
043
,600
49.5
31,
535
22,5
00
5 3
1.00
012
.566
10.6
815
1 /2
5 1 /
869
1,20
056
,500
NC
50 (
4 1 /
2 IF
)6
5 /8
3 1,
416,
200
57,8
0059
.16
1,83
430
,000
HT
5088
,800
53,3
00
5 1 /
24
0.75
011
,192
11.7
646
5 5 /
861
5,60
062
,200
5 1 /
2F
H7
41,
265,
800
55,9
0055
.21
1,71
229
,200
HT
5577
,200
46,3
00
5 7 /
84
0.93
814
.542
15.6
306
3 /8
679
9,80
082
,700
XT
577
41,
403,
100
106,
200
65.3
82,
027
63,7
00
6 5 /
85
0.81
314
.837
19.2
857
1 /8
6 3 /
481
6,00
010
2,00
06
5 /8
FH
85
1,44
8,40
073
,700
73.4
02,
,275
38,4
00
Sp
iral
-Wat
e®H
eavy
Wei
gh
t D
rill
Pip
e
Tub
eTo
ol J
oin
tW
eig
ht
(lb
)
No
min
al T
ub
eD
imen
sio
ns
Mec
han
ical
P
rop
erti
es T
ub
e
Mec
han
ical
P
rop
erti
es
Too
l Jo
int
Ap
pro
x.
Incl
. Tu
be
&
Too
l Jo
ints
Dimensional Data - Range II
NO
TE
:3
3/16
” S
pira
l-Wat
eTM,
prev
ious
ly r
efer
red
to a
s 2-
7/8”
, is
man
ufac
ture
d in
tegr
al o
nly
(non
-wel
ded)
.
Cen
.E
nd
47
DR
ILL
CO
LL
AR
S
Care And MaintenanceInitial Make UpEven though quality connections are heavily coatedwith phosphate, thread damage is not always pre-vented. A generous and thorough application of high-quality thread dope (40 to 60 percent metallic zincminimum) will help prevent galling.
New connections should be “walked in” with chaintongs. Always use the recommended make-up torquefor the thread design. Exercise care to maintain calibrated torque measuring and indicating gauges forfuture use. After initial make-up, break-out the con-nection, visually inspect, redope and make-up twomore times before running in the hole.
Note: Monitor break-out torque, it should be lessthan or no greater than make-up torque. If itis greater, the connection should be cleaned,inspected and repaired, before it is made upagain.
MaintenanceUse thread protectors on both connections when handling drill collars. Alternate different joints on eachtrip. Clean and inspect the individual connections.
Qualified personnel should periodically conduct amagnetic particle/black light inspection. Collars thatare left idle or put in storage, should be cleaned,inspected, repaired and rust-proofed, as necessarybefore installing thread protectors.
Field WeldingExtreme caution should be used when welding drillcollar material in the field. This material is high alloysteel, carefully heat-treated to provide optimum per-formance. When repair welding or hardbanding, useproper preheat, interpass and post-heat temperaturesto prevent cracking and metallurgical degradation ofthe collar.
Your Grant Prideco authorized repair facility can pro-vide welding repair service to factory specifications toensure weld area integrity. Contact your representa-tive today for more information.
Drill Collars
48
Care And Maintenance
Bending Strength RatiosSizes below six inches should have a BSR of 2.25:1to 2.75:1. Conditions which require high rpm andsmall collars compared to the hole size, use 2.25:1 to2.85:1. For abrasive conditions, use 2.50:1 to 3.00:1.If the rpm is kept low and the collars are closer to thehole size, use 2.25:1 to 3.20:1. In corrosive environ-ments, use 2.50:1 to 3.00:1.
3”
RCold Work
Shoulder Area
1” Radius
Shoulder Area
A
2”Radius
2” Radius
3”3”
16”
18”
20”
C
B
A
Slip and Elevator Recesses
B
C
49
Drill Elevator Slip ElevatorCollar Recess Recess Recess
Diameter Diameter Diameter RadiusA B C R
(in) (in) (in) (in)
4 1/8 3 11/16 3 3/4 1/8
4 3/4 4 1/4 4 3/8 1/8
5 4 1/2 4 5/8 1/8
6 5 3/8 5 1/2 1/8
6 1/4 5 5/8 5 3/4 1/8
6 1/2 5 7/8 6 1/8
7 1/4 6 1/2 6 3/4 3/16
7 3/4 7 7 1/4 3/16
8 7 1/4 7 1/2 3/16
8 1/4 7 1/2 7 3/4 3/16
9 8 1/8 8 1/2 1/4
9 1/2 8 5/8 9 1/4
9 3/4 8 7/8 9 1/4 1/4
10 9 1/8 91/2 1/4
11 10 1/8 10 1/2 1/4
Slip and Elevator Recess Dimensions
Drill Collar Min. Min. Min.Diameter Yield Strength Tensile Strength Hardness
(in) (psi) (psi) (BHN)
31/8 thru 67/8 110,000 140,000 285
7 thru 11 100,000 135,000 285
Materials Mechanical Properties
50
Recommended Minimum Make-upTorque for Rotary Shouldered DrillCollar Connections
3 *2,500 *2,500 *2,500*3390 *3390 *3390
API NC 23 3 1/8 *3,300 *3,300 2,600*4474 *4474 3525
3 1/4 4,000 3,400 2,6005423 *4610 3525
3 *3,800 *3,800*5152 *5152
2 7/8 PAC3
3 1/8 *4,900 4,2006644 5694
31/4 5,200 4,2007050 5694
2 3/8 API IF or 3 1/2 *4,600 *4,600*6237 *6237
API NC 26 or 3 3/4 5,500 4,7007457 6372
2 3/8 Slim Hole
2 7/8 Extra Hole or 3 3/4 *4,100 *4,100*5559 *5559
3 1/2 Dbl. Streamline 3 7/8 *5,300 *5,300or *7186 *7186
2 7/8 Mod. Open 4 1/8 *8,000 *8,000*10847 *10847
2 7/8 API IF or 3 7/8 *4,600 *4,600*6237 *6237
API NC 31 or 4 1/8 *7,300 *7,300*9897 *9897
4 1/4 *8,800 *8,800*11931 *11931
3 1/2 Slim Hole 4 1/2 10,000 9,30013558 12609
4 1/4
API NC 35 4 3/4
5
3 1/2 Extra Hole or 4 1/4
4 Slim Hole or 4 1/2
4 3/4
3 1/2 Mod. Open 5
5 1/4
Size Type OD 1 1 1/4 1 1/2(in)
Connection Bore of Drill Collar (in)
51
2,9003932
2,9003932
2,9003932
3,70050173,7005017
*4,100*5559
*5,3007186
7,40010033
*4,600 *4,600*6237 *6237
*7,300 6,800*9897 9220
8,100 6,80010982 9220
8,100 6,80010982 9220
*8,900 *8,900 *8,900 7,400*12067 *12067 *12067 1003312,100 *10,800 9,200 7,40016405 14643 12474 1003312,100 10,800 9,200 7,40016405 14643 12474 10033*5,100 *5,100 *5,100 *5,100
6915 6915 6915 6915*8,400 *8,400 *8,400 *8,200*11389 11389 11389 11118
*11,900 11,700 10,000 8,200*16134 15863 13558 1111813,200 11,700 10,000 8,20017897 15863 13558 1111813,200 11,700 10,000 8,20017897 15863 13558 11118
1 3/4 2 2 1/4 2 1/2 2 13/16
Bore of Drill Collar (in)
Foot-PoundNewton-Meters
52
3 1/2 API IF or 4 3/4
API NC 38 or 5
5 1/4
4 1/2 Slim Hole5 1/24 3/4
53 1/2 H 904
5 1/4
5 1/2
4 Full Hole 5
API NC 40 or 5 1/4
4 Mod Open or 5 1/2
5 3/4
4 1/2 Dbl. Streamline6
5 1/4
5 1/2
4 H 904 5 3/4
6
6 1/4
5 1/2
5 3/4
4 1/2 API Regular6
6 1/4
Connection Bore of Drill Collar (in)
Recommended Minimum Make-upTorque for Rotary Shouldered DrillCollar Connections
Size Type OD 1 1 1/4 1 1/2(in)
53
1 3/4 2 2 1/4 2 1/2 2 13/16
Bore of Drill Collar (in)
Foot-PoundNewton-Meters
*9,900 *9,900 *9,900 *9,900 *8,30013423 13423 13423 13423 *11253
*13,800 *13,800 12,800 10,900 8,300*18710 *18710 17354 14778 11253
16,000 14,600 12,800 10,900 8,30021693 19795 17354 14778 11253
16,000 14,600 12,800 10,900 8,30021693 19795 17354 14778 11253
*8,700 *8,700 *8,700 *8,700 *8,700*11796 *11796 *11796 *11796 *11796
*12,700 *12,700 *12,700 12,700 10,400*17219 *17219 *17219 17219 14101
*16,900 16,700 15,000 13,100 10,400*22913 22642 20337 17761 14101
18,500 16,700 15,000 13,100 10,40025083 22642 20337 17761 14101
*10,800 *10,800 *10,800 *10,800 *10,800*14643 *14643 *14643 *14643 *14643
*15,100 *15,100 *15,100 14,800 12,100*20473 *20473 *20473 20066 16405
*19,700 18,600 16,900 14,800 12,100*26710 25218 22913 20066 16405
20,400 18,600 16,900 14,800 12,10027659 25218 22913 20066 16405
20,400 18,600 16,900 14,800 12,10027659 25218 22913 20066 16405
*12,500 *12,500 *12,500 *12,500*16948 *16948 *16948 *16948
*17,300 *17,300 *17,300 *16,500*23456 *23456 *23456 22371
*22,300 21,500 19,400 16,500*30235 *29150 26303 22371
23,500 21,500 19,400 16,50031862 29150 26303 22371
23,500 21,500 19,400 16,50031862 29150 26303 22371
*15,400 *15,400 *15,400 *15,400*20880 *20880 *20880 *20880
*20,300 *20,300 19,400 16,200*27523 *27523 26303 21964
23,400 21,600 19,400 *16,20031726 29286 26303 21964
23,400 21,600 19,400 16,20031726 29286 26303 21964
54
5 1/4 *20,600*27930
6 25,000API NC 44 33895
6 1/4 25,00033895
6 1/2 25,00033895
5 1/2 *12,900*17490
5 3/4 *17,900*24269
4 1/2 API Full Hole 6 *23,300*31591
6 1/4 27,00036607
6 1/2 27,00036607
4 1/2 Extra Hole 5 3/4
API NC 46 6
4 API IF 6 1/4
4 1/2 Semi F 6 1/2
5 Dbl Streamline 6 3/4
4 1/2 Mod Open 6 3/4
5 3/4
6
4 1/2 H 904 6 1/4
6 1/2
6 3/4
6 1/4
6 1/25 H 904
6 3/4
7
Size Type OD 1 1/2 1 3/4 2(in)
Connection Bore of Drill Collar (in)
Recommended Minimum Make-upTorque for Rotary Shouldered DrillCollar Connections
55
*20,600 *20,600 18,000*27930 *27930 24405
23,300 21,200 18,00031591 28743 24405
23,300 21,200 18,00031591 28743 24405
23,300 21,200 18,00031591 28743 24405
*12,900 *12,900 *12,900 *12,900*17490 *17490 *17490 *17490
*17,900 *17,900 *17,900 17,700*24269 *24269 *24269 23998
*23,300 22,800 19,800 17,700*31591 30913 26845 23998
*25,000 22,800 19,800 17,70033895 30913 26845 23998
25,000 22,800 19,800 17,70033895 30913 26845 23998
*17,600 *17,600 *17,600 *17,600*23862 *23862 *23862 *23862
*23,200 *23,200 22,200 20,20031455 31455 30099 27388
28,000 25,500 22,200 20,20037963 34573 30099 27388
28,000 25,500 22,200 20,20037963 34573 30099 27388
28,000 25,500 22,200 20,20037963 34573 30099 27388
*17,600 *17,600 *17,600 *17,600*23862 *23862 *23862 *23862
*23,400 *23,400 23,000 21,000*31726 *31726 31184 28472
28,500 26,000 23,000 21,00038641 35251 31184 28472
28,500 26,000 23,000 21,00038641 35251 31184 28472
28,500 26,000 23,000 21,00038641 35251 31184 28472
*25,000 *25,000 *25,000 *25,000*33895 *33895 *33895 *33895
*31,500 *31,500 29,500 27,000*42708 *42708 39997 36607
35,000 33,000 29,500 27,00047453 44742 39997 36607
35,000 33,000 29,500 27,00047453 44742 39997 36607
2 1/4 2 1/2 2 13/16 3 3 1/4
Bore of Drill Collar (in)
Foot-PoundNewton-Meters
56
Size Type OD 2 2 1/4 2 1/2(in)
4 1/2 API IF or 6 1/4 *22,800 *22,800*30913 *30913
API NC 50 or 6 1/2 *29,500 *29,50039997 *39997
5 Extra Hole or 6 3/4 *36,000 35,500*48809 48132
5 Mod Open or 7 38,000 35,50051521 48132
5 1/2 Dbl. Streamline 7 1/4 38,000 35,500or Semi IF 51521 48132
6 3/4 *34,000 *34,400*46098 46640
7 *41,500 40,0005 1/2 H 904 *56266 54233
7 1/4 42,500 40,00057622 54233
7 1/2 42,500 40,00057622 54233
6 3/4 *31,500 *31,500*42708 *42708
7 *39,000 *39,0005 1/2 API Regular *52877 *52877
7 1/4 42,000 39,50056944 53555
7 1/2 42,000 39,50056944 53555
7 *32,500*44064
7 1/4 *40,5005 1/2 API Full Hole *54911
7 1/2 *49,00066435
7 3/4 51,50069825
7 1/4 *40,00054233
7 1/2 *48,500API NC 56 *65757
7 3/4 51,00069147
8 51,00069147
Connection Bore of Drill Collar (in)
Recommended Minimum Make-upTorque for Rotary Shouldered Drill Collar Connections
57
2 13/16 3 3 1/4 3 1/2 3 3/4
Bore of Drill Collar (in)
Foot-PoundNewton-Meters
*22,800 *22,800 *22,800*30913 *30913 *30913
*29,500 *29,500 26,500*39997 *39997 35929
32,200 30,000 26,50043657 40675 35929
32,000 30,000 26,50043386 40675 35929
32,000 30,000 26,50043386 40675 35929
*34,000 34,000*46098 46098
36,500 34,00049487 46098
36,500 34,00049487 46098
36,500 34,00049487 46098
*31,500 *31,500*42708 *42708
36,000 33,50048809 45420
36,000 33,50048809 45420
36,000 33,50048809 45420
32,500 32,500 *32,50044064 44064 *44064
*40,500 *40,000 *40,500*54911 *54233 *54911
47,000 45,000 41,50063723 61012 56266
47,000 45,000 41,50063723 61012 56266
*40,000 *40,000 *40,000*54233 *54233 *54233
48,000 45,500 42,00065079 61690 56944
48,000 45,000 42,00065079 61012 56944
48,000 45,000 42,00065079 61012 56944
58
7 1/2 *46,000*62368
7 3/4 *55,0006 5/8 API Regular *74570
8 57,00077282
8 1/4 57,00077282
7 1/2 *46,000*62368
7 3/4 *55,0006 5/8 H 904 *74570
8 59,500*80671
8 1/4 59,50080671
8 *54,000*73214
8 1/4 *64,000*86772
API NC 61 8 1/2 72,00097619
8 3/4 72,00097619
9 72,00097619
8 *56,000*75926
8 1/4 *66,000*89484
8 1/2 74,0005 1/2 API IF 100331
8 3/4 74,000100331
9 74,000100331
9 1/4 74,000100331
8 1/2
8 3/4
6 5/8 API Full Hole 9
9 1/4
9 1/2
Connection Bore of Drill Collar (in)
Recommended Minimum Make-upTorque for Rotary Shouldered DrillCollar Connections
Size Type OD 2 2 1/4 2 1/2(in)
59
*46,000 *46,000 *46,000*62368 *62368 *62368
53,000 50,000 47,00071858 67791 63723
53,000 50,000 47,00071858 67791 63723
53,000 50,000 47,00071858 67791 63723
*46,000 *46,000 *46,000*62368 *62368 *62368
55,000 53,000 49,500*74570 71858 67113
*56,000 53,000 49,500*75926 71858 67113
56,000 53,000 49,50075926 71858 67113
*54,000 *54,000 *54,000*73214 *73214 *73214
*64,000 *64,000 61,000*86772 *86772 82705
68,000 65,000 61,00092196 88128 82705
68,000 65,000 61,00092196 88128 82705
68,000 65,000 61,00092196 88128 82705
*56,000 *56,000 *56,000 *56,000*75926 *75926 *75926 *75926
*66,000 *66,000 63,000 59,000*89484 *89484 85417 79993
70,000 67,000 63,000 59,00094907 90840 85417 79993
70,000 67,000 63,000 59,00094907 90840 85417 79993
70,000 67,000 63,000 59,00094907 90840 85417 79993
70,000 67,000 63,000 59,00094907 90840 85417 79993
*67,000 *67,000 *67,000 *67,000 66,500*90840 *90840 *90840 *90840 90162
*78,000 *78,000 76,000 72,000 66,500*105754 *105754 103042 97619 90162
83,000 80,000 76,000 72,000 66,500112533 108465 103042 97619 90162
83,000 80,000 76,000 72,000 66,500112533 108465 103042 97619 90162
83,000 80,000 76,000 72,000 66,500112533 108465 103042 97619 90162
2 13/16 3 3 1/4 3 1/2 3 3/4
Bore of Drill Collar (in)
Foot-PoundNewton-Meters
60
9
9 1/4
9 1/2API NC 70
9 3/4
10
10 1/4
10
10 1/4
API NC 77 10 1/2
10 3/4
11
8
7 H 904 8 1/4
8 1/2
8 1/2
8 3/47 5/8 API Regular
9
9 1/4
9 1/2
9
7 5/8 H 904 9 1/4
9 1/2
Connection Bore of Drill Collar (in)
Recommended Minimum Make-upTorque for Rotary Shouldered DrillCollar Connections
Size Type OD 2 2 1/4 2 1/2(in)
61
*75,000 *75,000 *75,000 *75,000 *75,000*101686 *101686 *101686 *101686 *101686
*88,000 *88,000 *88,000 *88,000 *88,000*119312 *119312 *119312 *119312 *119312
*101,000 *101,000 100,000 95,000 90,000*136938 *136938 135582 128803 122024
107,000 105,000 100,000 95,000 90,000145073 142361 135582 128803 122024
107,000 105,000 100,000 95,000 90,000145073 142361 135582 128803 122024
107,000 105,000 100,000 95,000 90,000145073 142361 135582 128803 122024
*107,000 *107,000 *107,000 *107,000*145073 *145073 *145073 *145073
*122,000 *122,000 *122,000 *122,000*165410 *165410 *165410 *165410
*138,000 *138,000 133,000 128,000*187103 *187103 180324 173545
143,000 138,000 133,000 128,000193882 187103 180324 173545
143,000 138,000 133,000 128,000193882 187103 180324 173545
*53,000 *53,000 *53,000 *53,000*71858 *71858 *71858 *71858
*63,000 *63,000 *63,000 60,500*85417 *85417 *85417 *82027
71,500 68,500 65,000 60,50096941 92874 88128 82027
*60,000 *60,000 *60,000 *60,000*81349 *81349 *81349 *81349
*71,000 *71,000 *71,000 *71,000*96263 *96263 *96263 *96263
*83,000 *83,000 79,000 74,000*112533 *112533 107110 100331
88,000 83,000 79,000 74,000119312 112532 107110 100331
88,000 83,000 79,000 74,000119312 112532 107110 100331
*72,000 *72,000 *72,000 *72,000*97619 *97619 *97619 *97619
*85,500 *85,500 *85,500 *85,500*115922 *115922 *115922 *115922
*98,000 *98,000 *98,000 95,500*132870 *132870 *132870 129481
2 13/16 3 3 1/4 3 1/2 3 3/4
Bore of Drill Collar (in)
Foot-PoundNewton-Meters
62
10
8 5/8 API Regular 10 1/4
10 1/2
10 1/48 5/8 H 904
10 1/2
7 H 904 8 3/4
9
9 1/4
7 5/8 API Regular 9 1/2
9 3/4
10
9 3/4
107 5/8 H 904
10 1/4
10 1/2
8 5/8 API Regular 10 3/4
11
10 3/4
8 5/8 H 904 11
11 1/4
Connection Bore of Drill Collar (in)
*NOTE 1: Torque figures preceded by an asterisk indicate that the weakermember for the corresponding outside diameter (OD) and bore is theBOX. For all other torque values the weaker member is the PIN.
NOTE 2: In each connection size and type group, torque values apply to allconnection types in the group, when used with the same drill collaroutside diameter and bore, i.e. 2 3/8, API IF, API NC 26, and 2 7/8 SlimHole connections used with 3 1/2 x 1 1/4 drill collars all have the sameminimum make-up torque of 4,600 ft.-lb., and the BOX is the weaker member.
Recommended Minimum Make-upTorque for Rotary Shouldered Drill Collar Connections
Size Type OD 2 2 1/4 2 1/2(in)
(with lowtorque face)
(with lowtorque face)
(with lowtorque face)
(with lowtorque face)
(with lowtorque face)
63
*108,000 *108,000 *108,000 *108,000*146428 *146428 *146428 *146428
*123,000 *123,000 *123,000 *123,000*166766 *166766 *166766 *166766
139,000 134,000 129,000 123,000188459 181680 174901 166766
*112,500 *112,500 *112,500 *112,500*152530 *152530 *152530 *152530
*128,500 *128,500 *128,500 *128,500*174223 *174223 *174223 *174223
*67,500 *67,500 66,500 62,000*91518 *91518 90162 84061
74,000 71,000 66,500 62,000100331 96263 90162 84061
*72,000 *72,000 *72,000 *72,000*97619 *97619 *97619 *97619
*85,000 *85,000 82,000 77,000*115245 *115245 111177 104398
91,000 87,000 82,000 77,000123379 117956 111177 104398
91,000 87,000 82,000 77,000123379 117956 111177 104398
*91,000 *91,000 *91,000 *91,000*123379 *123379 *123379 *123379
*105,000 *105,000 103,500 98,000*142361 *142361 140327 132870
112,500 108,000 103,500 98,000152530 146428 140327 132870
112,500 108,000 103,500 98,000152530 146428 140327 132870
*112,000 *112,000 *112,000 *112,000*151852 *151852 *151852 *151852
*129,000 *129,000 *129,000 *129,000*174901 *174901 *174901 *174901
*92,500 *92,500 *92,500 *92,500*125413 *125413 *125413 *125413
*110,000 *110,000 *110,000 *110,000*149140 *149140 *149140 *149140
*128,000 *128,000 *128,000 *128,000*173545 *173545 *173545 *173545
2 13/16 3 3 1/4 3 1/2 3 3/4
Bore of Drill Collar (in)
1 Basis of calculations for recommended make-up torque assumed the use of athread compound containing a 0.08 coefficient of friction, applied thoroughly toall threads and shoulders, and using the modified Jack Screw formula inAppendix A, paragraph A.8 and a unit stress of 62,500 psi in the box or pin,whichever is weaker.
2 Normal torque range is tabulated value plus 10%. Higher torque values may beused under extreme conditions.
3 Make-up torque for 27/8 PAC connection is based on 87,500 psi stress and otherfactors listed in footnote1.
4 Make-up torque for H-90 connection is based on 56,200 psi stress and otherfactors listed in footnote1.
Foot-PoundNewton-Meters
64
DRILLCOLLAR OD
ELEVATORGROOVE DIA
SLIPGROOVE DIA RADIUS
A B C R+- 1/64 +- 1/32
3 3/4
4 3/8
4 5/8
4 7/8
5 1/8
5 1/4
5 1/2
5 3/4
6
6 1/4
6 1/2
6 3/4
7
7 1/4
7 1/2
7 3/4
8
8 1/2
9
9 1/4
9 1/2
10 1/2
1/8
1/8
1/8
1/8
1/8
1/8
1/8
1/8
1/8
3/16
3/16
3/16
3/16
3/16
3/16
3/16
3/16
1/4
1/4
1/4
1/4
1/4
3 11/16
4 1/4
4 1/2
4 3/4
5
5 1/8
5 3/8
5 5/8
5 7/8
6
6 1/4
6 1/2
6 3/4
7
7 1/4
7 1/2
7 3/4
8 1/8
8 5/8
8 7/8
9 1/8
10 1/8
4 1/8
4 3/4
5
5 1/4
5 1/2
5 3/4
6
6 1/4
6 1/2
6 3/4
7
7 1/4
7 1/2
7 3/4
8
8 1/4
8 1/2
9
9 1/2
9 3/4
10
11
NOTE:ON REWORK, MINIMUM DISTANCEFROM FACE OF BOXTO ELEVATORSHOULDER OR ENDOF HARDBANDINGSHOULD BE ALENGTH EQUIVALENTTO DEPTH OF BOXOR BOREBACK PLUSTWO INCHES
Groove Machining ForElevators and Slips
65
Hardbanding
66
Drill CollarOD(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
2 7/8 19 18 1628 27 24
3 21 20 1831 30 27
3 1/8 22 22 2033 33 30
3 1/4 26 24 2239 36 33
3 1/2 30 29 2745 43 40
3 3/4 35 33 3252 49 48
4 40 39 37 35 32 2960 58 55 52 48 43
4 1/8 43 41 39 37 35 3264 61 58 55 52 48
4 1/4 46 44 42 40 38 3568 65 62 60 56 52
4 1/2 51 50 48 46 43 4176 74 71 68 64 61
4 3/4 54 52 50 4780 77 74 70
5 61 59 56 5391 88 83 79
5 1/4 68 65 63 60101 97 94 89
5 1/2 75 73 70 67112 108 104 100
5 3/4 82 80 78 75122 119 116 112
6 90 88 85 83134 131 126 124
6 1/4 98 96 94 91146 143 140 135
6 1/2 107 105 102 99159 156 152 147
6 3/4 116 114 111 108172 170 165 161
7 125 123 120 117186 183 179 174
7 1/4 134 132 130 127199 196 193 189
7 1/2 144 142 139 137214 211 207 204
7 3/4 154 152 150 147229 226 223 218
Drill Collar Weightlb/ft, kg/m
Drill Collar ID (in)
67
Pound per footKilogram per meter
2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
44655074578564 6095 8972 67 64 60
107 100 95 8979 75 72 68
118 111 107 10188 83 80 76 72
131 123 119 113 10796 91 89 85 80
143 135 132 126 119105 100 98 93 89156 149 146 138 132114 110 107 103 98 93 84170 163 159 153 146 138 125124 119 116 112 108 103 93184 177 172 166 161 153 138133 129 126 122 117 113 102198 192 187 181 174 168 152144 139 136 132 128 123 112214 207 202 196 190 183 166
68
Drill CollarOD(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
8 165 163 160 157245 242 238 233
8 1/4 176 174 171 168262 257 254 250
8 1/2 187 185 182 179278 275 270 266
9 210 208 206 203312 309 306 302
9 1/2 234 232 230 227348 345 342 337
9 3/4 248 245 243 240369 364 361 357
10 261 259 257 254388 385 382 377
11 317 315 313 310471 468 465 461
12 379 377 374 371563 560 557 551
Drill Collar Weightlb/ft, kg/m
Drill Collar ID (in)
Drill CollarOD(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
2 7/8 589 558 496267 253 225
3 651 620 558295 281 253
3 1/8 682 682 620309 309 281
3 1/4 806 744 682365 337 309
3 1/2 930 899 837422 407 400
3 3/4 1,085 1,023 992492 463 450
4 1,240 1,209 1,147 1,085 992 899562 548 520 492 450 407
4 1/8 1,333 1,271 1,209 1,147 1,085 992604 577 548 520 492 450
4 1/4 1,426 1,364 1,302 1,240 1,178 1,085647 619 590 562 534 492
Drill Collar ID (in)
31ft (lb), 31 ft (kg)
Note 1: Refer to API Spec 7. Table 6.1 for API standard drill collardimensions.
69
Pound per footKilogram per meter
NOTE 2: For special configurations of drill collars, consult manufac-turer for reduction in weight.
PoundKilogram
2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
154 150 147 143 138 133 122229 223 218 213 205 198 181165 160 158 154 149 144 133245 238 235 229 221 214 198176 172 169 165 160 155 150262 256 251 245 238 230 223200 195 192 188 184 179 174297 290 285 279 273 266 259224 220 216 212 209 206 198333 327 321 315 311 306 294237 232 229 225 221 216 211352 345 340 334 328 321 314251 246 243 239 235 230 225373 366 361 355 349 342 334307 302 299 295 291 286 281456 449 444 438 432 425 418368 364 361 357 352 347 342547 541 537 531 523 516 508
2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
70
Drill CollarOD(in) 1 1 1/4 1 1/2 1 3/4 2 2 1/4
4 1/2 1,581 1,550 1,488 1,426 1,333 1,271717 703 675 646 604 576
4 3/4 1,674 1,612 1,550 1,457759 731 703 660
5 1,891 1,829 1,736 1,643857 829 787 745
5 1/4 2,108 2,015 1,953 1,860956 913 885 843
5 1/2 2,325 2,263 2,170 2,0771,055 1,026 984 942
5 3/4 2,542 2,480 2,418 2,3251,152 1,125 1,097 1,055
6 2,790 2,728 2,635 2,5731,266 1,237 1,195 1,167
6 1/4 3,038 2,976 2,914 2,8211,378 1,350 1,322 1,280
6 1/2 3,317 3,255 3,162 3,0691,505 1,476 1,434 1,392
6 3/4 3,596 3,534 3,441 3,3481,631 1,603 1,561 1,519
7 3,875 3,813 3,720 3,6271,758 1,730 1,687 1,645
7 1/4 4,154 4,092 4,030 3,9371,884 1,856 1,828 1,786
7 1/2 4,464 4,402 4,309 4,2472,025 1,997 1,955 1,926
7 3/4 4,774 4,712 4,650 4,5572,165 2,137 2,109 2,067
8 5,115 5,053 4,960 4,8672,320 2,292 2,250 2,208
8 1/4 5,456 5,394 5,301 5,2082,475 2,447 2,404 2,362
8 1/2 5,797 5,735 5,642 5,5492,629 2,601 2,559 2,517
9 6,510 6,448 6,386 6,2932,953 2,925 2,897 2,854
9 1/2 7,254 7,192 7,130 7,0373,290 3,262 3,234 3,192
9 3/4 7,688 7,595 7,533 7,4403,487 3,445 3,417 3,375
10 8,091 8,029 7,967 7,8743,670 3,642 3,614 3,572
11 9,827 9,765 9,703 9,6104,457 4,429 4,401 4,359
12 11,749 11,687 11,594 11,5015,329 5,301 5,259 5,217
Drill Collar Weight31ft(lb), 31ft(kg)
Drill Collar ID (in)
NOTE 1: Refer to API Spec. 7. Table 6.1 for API standard drill collars dimensions.
NOTE 2: For special configurations of drill collars, consult manufacturer for reduc-tion in weight.
71
Pound Kilogram
2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4
1,364618
1,550703
1,767801
1,984 1,860899 843
2,232 2,077 1,984 1,8601,012 942 899 8432,449 2,325 2,232 2,1081,111 1,055 1,012 9562,728 2,573 2,480 2,356 2,2321,237 1,167 1,125 1,069 1,0122,976 2,821 2,759 2,635 2,4801,350 1,280 1,251 1,195 1,1253,255 3,100 3,038 2,883 2,7591,476 1,406 1,378 1,308 1,2523,534 3,410 3,317 3,193 3,038 2,883 2,6041,603 1,547 1,505 1,448 1,378 1,308 1,181 3,844 3,689 3,596 3,472 3,348 3,193 2,8831,744 1,673 1,631 1,575 1,519 1,448 1,3084,123 3,999 3,906 3,782 3,627 3,503 3,1621,870 1,814 1,772 1,715 1,645 1,589 1,4344,464 4,309 4,216 4,092 3,968 3,813 3,4722,024 1,955 1,912 1,856 1,800 1,730 1,5754,774 4,650 4,557 4,433 4,278 4,123 3,7822,165 2,109 2,067 2,011 1,940 1,870 1,7155,115 4,960 4,898 4,774 4,619 4,464 4,1232,320 2,250 2,222 2,165 2,095 2,025 1,8705,456 5,332 5,239 5,115 4,960 4,805 4,6502,475 2,419 2,376 2,320 2,250 2,180 2,1096,200 6,045 5,952 5,828 5,704 5,549 5,3942,812 2,742 2,700 2,644 2,587 2,517 2,4476,944 6,820 6,696 6,572 6,479 6,386 6,1383,150 3,093 3,037 2,981 2,939 2,897 2,7847,347 7,192 7,099 6,975 6,851 6,696 6,5413,333 3,262 3,220 3,164 3,108 3,037 2,9677,781 7,626 7,533 7,409 7,285 7,130 6,9753,529 3,459 3,417 3,361 3,304 3,234 3,1649,517 9,362 9,269 9,145 9,021 8,866 8,7114,317 4,247 4,204 4,148 4,092 4,022 3,951
11,408 11,284 11,191 11,067 10,912 10,757 10,6025,175 5,118 5,076 5,020 4,950 4,879 4,809
72
73
Drill Collar Bending Strength Ratios
74
75
Drill Collar Bending Strength Ratios
76
77
Drill Collar Bending Strength Ratios
78
79
Drill Collar Bending Strength Ratios
80
81
Drill Collar Bending Strength Ratios
82
83
Drill Collar Bending Strength Ratios
84
85
Drill Collar Bending Strength Ratios
86
Interchangeable Connection Table
Connection Name
Internal Flush(IF)
Extra Hole(XH)
External Flush(EF)
Double Streamline(DSL)
Full Hole(FH)
Slim Hole(SH)
NumberedConnection (NC)
Size
26
2 3/8
2 7/8
3 1/2
2 7/8
31
2 7/8
3 1/2
87
38
3 1/2
4 1/2
40 46 50
3 1/2
4 1/2
4
4 1/2
4 1/2 5
5 1/2
4 1/2
4
4
88
6 1/8 4 1/2 3.875
6 1/4 4 1/2 3.750
6 3/4 4 1/2 3.250
4 1/2 2.125
5 1/2 4.225
5 1/2 3.725
6 5/8 6.405
6 5/8 6.280
7 *6.812
6 5/8 6.030
7 6.562
7 6.812
7 5/8 7.500
7 5.437
7 5/8 7.125
7 5/8 6.375
8 5/8 *8.625
11 8 5/8 8.250
9 5/8 9.000
10 3/4 *11.250
13 3/4 10 3/4 9.750
14 3/4 11 3/4 10.750
17 1/2 13 3/8 11.250
20 16 14.000
24 18 5/8 15.500
26 20 16.000
7 7/8
12 1/4
8 3/8
8 1/2
8 3/4
9 1/2
10 5/8
9 7/8
Casing Size Ideal DrillHole Size To Be Run
(in) (in) Min.(in)
Ideal Drill Collar Range
* The minimum size drill collar, calculated from the Lubinski and Hock equation, withthe specific sizes of hole and casing combination, is too large for conventional fish-ing tools. When the minimum drill collar diameter is too large to washover and/orcatch with an overshot, other steps should be taken. Some of the possibilities areas follows:
• Use turned down casing couplings.• Use integral joints on casing.• Under-ream the hole.• Run smaller size casing.
* Use a packed hole assembly instead of a pendulum.** Not API standard size drill collar.
89
4.750 4 1/8, 4 3/4
4.875 4 1/8, 4 3/4
5.125 3 1/2, 4 1/8, 4 3/4, 5
6.250 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4
6.250 4 3/4, 5, 6, 6 1/4
6.750 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4
6.750 6 1/2, 6 3/4
6.750 6 1/2, 6 3/4
6.750 6 3/4
7.125 6 1/4, 6 1/2, 6 3/4, 7
7.125 6 3/4, 7
7.625 6, 6 1/4, 6 1/2, 7, 7 1/4
7.875 7 3/4
8.000 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8
8.000 7 1/4, 7 3/4, 8
8.500 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4
8.500 8 1/4
8.875 8 1/4
10.125 9, 9 1/2, 9 3/4, 10
10.125 10
11.250 9 3/4, 10, 11
12.000 11, **12
13.375 **12
14.750 **14
16.750 **16
19.500 **16
Collar Range API Drill Collar
Max. Sizes Which Fall(in) in the Ideal Range (in)
90
SXD 8 - 16 200,000 8, 81/4, 9, 9
1/2, 93/4, 10, 11
SDD 4 - 12 100,000 4 1/8, 4
3/4, 5, 6, 6 1/4, 61/2,
63/4,7, 7
1/4, 73/4, 8, 8
1/4, 9,9
1/2, 93/4, 10
DB 3 1/2 - 11 1/4 65,000 3 1/2, 4
1/8, 43/4, 5, 6, 6 1/4, 6
1/2,
63/4, 7, 7
1/4, 73/4, 8, 8
1/4
B 3 1/2 - 9 55,000 3 1/2, 4
1/8, 43/4, 5, 6, 6 1/4, 6
1/2,
63/4, 7, 7
1/4, 73/4, 8
C 2 3/8 - 10 3/4 35,000 3 1/8, 3
1/2, 41/8, 4
3/4, 5, 6,
61/4, 6
1/2, 63/4
F 2 3/8 - 10 3/4 25,000 3 1/8, 3
1/2, 41/8, 4
3/4, 5, 6
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 41/8,, 4
3/4, 5, 6, 6 1/4, 61/2,
63/4,7, 7
1/4, 73/4, 8
H 3 1/2 - 10 3/4 80,000 31/2, 4
1/8, 43/4, 5, 6, 6
1/4,
61/2, 7, 7
1/4, 73/4, 8, 8
1/4, 9
AAX 2 7/8 - 7 1/4 55,000 3 1/8, 3
1/2, 41/8,, 4
3/4,, 5, 6, 6
1/4, 61/2, 6
3/4, 7, 71/4, 8
B 2 3/8 - 8 5/8 35,000 3 1/8, 3
1/2, 4 1/8, 4
3/4, 5, 6,
61/4, 6
1/2, 63/4
SDD 4 - 12 100,000 4 1/8, 4
3/4, 5, 6, 6 1/4, 61/2,
63/4, 7, 7
1/4, 73/4, 8, 8
1/4,
9, 9 1/2, 9
3/4, 10
SUPER A 3 1/2 - 11 1/4 65,000 3 1/2,, 4
1/4, 43/4 ,5, 6, 6 1/4,
61/2, 6
3/4, 7, 71/4, 7
3/4, 8, 81/4
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, 71/4, 8
SUPER C 2 3/8 - 7 35,000 3 1/8, 3
1/2, 41/8, 4
3/4, 5, 6,
6 1/4, 6
1/2, 63/4
TONG JAW CAPACITY APPLICABLE APITYPE SIZES (in) (ft-lbs.) DRILL COLLAR SIZES (in)
Rig Tongs
B.J. HUGHES COMPANY
JOY-WEB WILSON COMPANY
WOOLLEY COMPANY
91
KE
LLY
S
Kellys
92
AcrossFlat 11/16 11/4 11/2 13/4 2 21/4 21/2 23/4 27/8 3 31/4 31/2
21/2 18.3 17.1
3 25.8 24.0 21.8
31/2 35.6 33.5 31.0 28.2
41/4 47.9 44.7 41.3 39.3
51/4 73.5 71.6 69.7 65.5 61.0
6 89.6
Kelly Weights Pounds Per Foot(Drive Section)
Bore of Square Kelly
Square Kelly
Hexagon Kelly
AcrossFlat 11/4 11/2 13/4 2 21/4 21/2 23/4 27/8 3 31/4 31/2 4
3 22.3 20.5
31/2 30.1 27.9 25.4 22.6
33/4 35.3 33.2 30.7 27.9
41/4 39.6 36.4 32.9 31.0
427/32 56.4 53.3 49.8 47.9 45.9 41.7
51/4 60.9 59.0 57.1 52.9 48.4
6 73.5 63.2
Bore of Hexagon Kelly
93
94
Under ideal conditions, a new Drive Bushing assemblyshould be used when picking up a new kelly. If this is notpossible, the following checklist should be performed:
1. Inspect surfaces on Drive Bushing rollers for wear. Example: For a 51/4 inch Hex, if wearexceeds 1/8 inch, reverse the rollers.
2. Check clearance between roller face and side ofkelly. Example: For a 51/4 inch Hex, if clearance ismore than 1/8 inch, inspect roller assembly andKelly Bushing for excessive wear.
3. Inspect bottom taper of Drive Pins for wear anddamage. Replace as necessary.
4. Inspect for clearance between upper and lowerhalves, replace if clearance is zero.
Remember, a worn out Drive Bushing can severelydamage a new kelly.
Picking Up a New Kelly
95
SU
BS
NOTES:
1. Other lengths may be specified by the customer, example 48 inches.
2. Fishing neck (tong space) length, unless specifiedotherwise, is one half the overall length of the sub.For example, 18 inch fishing neck (tong space) ona 36 inch sub; 24 inch on a 48 inch sub.
3. Bevel Diameters- Make sure the bevel diameterson the subs match the bevel diameters on the con-nections.
SubsGeneral Notes on Subs
96
Types Of Subs
97
General Notes On SubsNOTES:
1. Other lengths may be specified by the customer, example 48 inches.2. Fishing neck (tong space) length, unless specifiedotherwise, is one half the overall length of the sub.For example, 18 inch fishing neck (tong space) on a36 inch sub; 24 inch on a 48 inch sub.3. Bevel Diameters:
A. If the connection is to screw onto a piece ofDrill 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 afloat bore) use the bevel diameters listed in column B in the top chart of drawing HB1017“Float Bore” in this section of the MachiningHandbook.
C. If the connection is to screw onto a Drill Collar(Collar, D/C) use the bevel diameters listed atthe bottom of the drawing of the specifiedconnection.
98
Kelly Saver Subs
99
Bit Sub
Lift Sub
100
Bit Box Float Bores
101
WE
LL
CO
NT
RO
L
Well Control
Height of Kick (ft) = Pit Gain ÷ Annular Capacityin Bbls/ftDensity 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 fromchoke movement will take about two seconds per1000’ of depth to travel down the annulus and upthe drill pipe to the DP gauge.
Sacks of Barite needed to Weight-Up Mud = BblsMud 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
102
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 0.1285 1/2 0.110 0.128 0.141 0.158
6 – 0.154 0.170 0.1926 1/2 – 0.183 0.203 0.228
7 – 0.213 0.238 0.2677 1/2 – 0.241 0.275 0.310
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 0.0735 1/2 0.066 0.074 0.081 0.088
6 0.079 0.087 0.096 0.1056 1/2 0.092 0.103 0.113 0.123
7 0.107 0.119 0.131 0.1437 1/2 0.123 0.137 0.150 0.164
(in Bbls/stroke) (in Bbls/stroke)
Well Control
MW Mud WeightSICP Shut in casing pressureSIDPP Shut in drill pipe pressureppg Pounds per gallonKWM Kill Weight MudOWM Original Weight MudDP Drill PipeBbls BarrelsStk Stroke
103
API Standard Drill Pipe Capacity and Displacement
Size Size NominalOD ID Weight Capacity Displacement(in) (in) (lb/ft) (bbl/ft) (bbl/ft)
2 3/8 1.81 6.6 0.0032 0.00282 7/8 2.15 10.4 0.0045 0.00413 1/2 2.76 13.3 0.0074 0.00513 1/2 2.60 15.5 0.0066 0.00584 3.34 14.0 0.0108 0.00574 1/2 3.82 16.6 0.0142 0.00644 1/2 3.64 20.0 0.0129 0.00775 4.28 19.5 0.0178 0.00755 1/2 4.78 21.9 0.0222 0.00875 1/2 4.67 24.7 0.0211 0.00966 5/8 4.86 22.2 0.0229 0.00876 5/8 5.96 25.2 0.0346 0.0098
Heavy Weight Drill Pipe
Size SizeOD ID Weight Capacity Displacement(in) (in) (lb/ft) (bbl/ft) (bbl/ft)
3 1/2 2.0625 25.3 0.00421 0.009214 2.5625 29.7 0.00645 0.010824 1/2 2.75 41.0 0.00743 0.014935 3.0 49.3 0.00883 0.017965 1/2 3.25 61.5 0.01030 0.022406 5/8 4.5 72.0 0.01970 0.02620
Additional capacities, displacements and weight can bedetermined from the following formulas:
CAPACITY = = bbls/ftID2
1029.4
DISPLACEMENT = = bbls/ftOD2 - ID2
1029.4
WEIGHT = DISPLACEMENT bbls/ft x 2747 lbs/bbl = lbs/ft
104
ID1
1 /2
1 3 /
42
2 1 /
42
1 /2
2 3 /
43
3 1 /
43
1 /2
3 3 /
44
4 1 /
4C
ap0.
0022
0.00
300.
0039
0.00
490.
0061
0.00
730.
0087
0.01
030.
0119
0.01
370.
0155
0.01
75
OD
(in
)#/
ft.36
.734
.532
.029
.2-
--
--
--
-4
Dis
p.0.
0133
0.01
250.
0116
0.10
6-
--
--
--
-4
1 /4
#/ft.
42.4
40.0
37.5
34.7
--
--
--
--
Dis
p.0.
0153
0.01
450.
0136
0.01
26-
--
--
--
-4
1 /2
#/ft.
48.1
45.9
43.4
40.6
--
--
--
--
Dis
p.0.
175
0.01
670.
0158
0.01
48-
--
--
--
-4
3 /4
#/ft.
54.3
52.1
49.6
46.8
43.6
--
--
--
-D
isp.
0.01
970.
0189
0.01
810.
0170
0.01
59-
--
--
--
5#/
ft.60
.858
.656
.153
.350
.1-
--
--
--
Dis
p.0.
0221
0.02
130.
0204
0.01
940.
0182
--
--
--
-5
1 /4
#/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 /2
#/ft.
74.8
72.6
70.1
67.3
64.1
60.6
56.8
--
--
-D
isp.
0.02
720.
0264
0.02
550.
0245
0.02
330.
0221
0.02
07-
--
--
5 3 /
4#/
ft82
.380
.177
.674
.871
.668
.164
.3-
--
--
Dis
p.0.
0299
0.02
910.
0282
0.02
720.
0261
0.02
480.
0234
--
--
-6
#/ft.
90.1
87.9
85.4
82.6
79.4
75.9
72.1
67.9
63.4
--
-D
isp.
0.03
280.
0320
0.03
110.
0301
0.02
890.
0276
0.02
620.
0247
0.02
31-
--
6 1 /
4#/
ft.98
.095
.893
.390
.587
.383
.880
.075
.871
.3-
--
Dis
p.0.
0356
0.03
490.
0339
0.03
290.
0318
0.03
050.
0291
0.02
760.
0259
--
-6
1 /2
#/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
--
-
Dri
ll C
olla
r C
apac
ity
and
Dis
pla
cem
ent
(bb
ls/f
t)
105
ID1
1 /2
1 3 /
42
2 1 /
42
1 /2
2 3 /
43
3 1 /
43
1 /2
3 3 /
44
4 1 /
4C
ap0.
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 /
4#/
ft.11
6.0
113.
811
1.3
108.
510
5.3
101.
898
.093
.889
.3-
--
Dis
p.0.
0422
0.04
140.
0405
0.03
950.
0383
0.03
700.
0356
0.03
410.
0325
--
-7
#/ft.
125.
012
2.8
120.
311
7.5
114.
311
0.8
107.
010
2.8
98.3
93.4
88.3
-D
isp.
0.04
550.
0447
0.04
380.
0427
0.04
160.
0403
0.03
890.
0374
0.03
580.
0340
0.03
217
1 /4
#/ft.
134.
013
1.8
129.
312
6.5
123.
311
9.8
116.
011
1.8
107.
310
2.4
97.3
-D
isp.
0.04
870.
0479
0.04
700.
0460
0.04
490.
0436
0.04
220.
0407
0.03
900.
0372
0.03
54-
7 1 /
2#/
ft.14
4.0
141.
813
9.3
136.
513
3.3
129.
812
6.0
121.
811
7.3
112.
410
7.3
-D
isp.
0.05
240.
0516
0.05
070.
0497
0.04
850.
0472
0.04
580.
0443
0.04
270.
0409
0.03
90-
7 3 /
4#/
ft.15
4.0
151.
814
9.3
146.
514
3.3
139.
813
6.0
131.
812
7.3
122.
411
7.3
-D
isp.
0.05
600.
0552
0.05
430.
0533
0.05
210.
0509
0.04
950.
0479
0.04
630.
0445
0.04
27-
8#/
ft.16
5.0
162.
816
0.3
157.
515
4.3
150.
814
7.0
142.
813
8.3
133.
412
3.3
122.
8D
isp.
0.06
000.
0592
0.05
830.
0573
0.05
610.
0549
0.05
350.
0520
0.05
030.
0485
0.04
670.
0447
8 1 /
4#/
ft17
6.0
173.
817
1.3
168.
516
5.3
161.
815
8.0
153.
814
9.3
144.
413
9.3
133.
8D
isp.
0.06
400.
0632
0.06
230.
0613
0.06
010.
0589
0.05
750.
0560
0.05
430.
0525
0.05
070.
0487
8 1 /
2#/
ft.18
7.0
184.
818
2.3
179.
517
6.3
172.
816
9.0
164.
816
0.3
155.
415
0.3
144.
8D
isp.
0.06
800.
0672
0.06
630.
0653
0.06
410.
0629
0.06
150.
0600
0.05
830.
0565
0.05
470.
0527
8 3 /
4#/
ft.19
9.0
196.
819
4.3
191.
518
8.3
184.
818
1.0
176.
817
2.3
167.
416
2.3
156.
8D
isp.
0.07
240.
0716
0.07
070.
0697
0.06
850.
0672
0.06
580.
0643
0.06
970.
0609
0.05
900.
0570
9#/
ft.21
0.2
208.
020
5.6
202.
719
9.6
196.
019
2.2
188.
018
3.5
178.
717
3.5
168.
0D
isp.
0.07
650.
0757
0.07
480.
0738
0.07
260.
0714
0.07
000.
0685
0.06
680.
0651
0.06
320.
0612
10#/
ft.26
0.9
258.
825
6.3
253.
425
0.3
246.
824
2.9
238.
823
4.3
229.
422
4.2
218.
7D
isp.
0.09
500.
0942
0.09
330.
0923
0.09
110.
0898
0.08
840.
0869
0.08
530.
0835
0.08
160.
0796
Dri
ll C
olla
r C
apac
ity
and
Dis
pla
cem
ent
(bb
ls/f
t)
(Co
nt.
)
106
Mud Density Buoyancy
(lb/gal) (lb/cu ft) (g/cc)
8.4 62.84 1.01 0.8728.6 64.33 1.03 0.8698.8 65.83 1.05 0.8669.0 67.32 1.08 0.8629.2 68.82 1.10 0.8599.4 70.32 1.12 0.8569.6 71.81 1.15 0.8539.8 73.31 1.17 0.850
10.0 74.80 1.20 0.84710.2 76.30 1.22 0.84410.4 77.80 1.24 0.84110.6 79.29 1.27 0.83810.8 80.79 1.29 0.83511.0 82.29 1.32 0.83211.2 83.78 1.34 0.82911.4 85.28 1.36 0.82611.6 86.77 1.39 0.82311.8 88.27 1.41 0.82012.0 89.77 1.44 0.81712.2 91.26 1.46 0.81412.4 92.76 1.48 0.81112.6 94.25 1.51 0.80712.8 95.75 1.53 0.80413.0 97.25 1.56 0.80113.2 98.74 1.58 0.79813.4 100.24 1.60 0.79513.6 101.74 1.63 0.79213.8 103.23 1.65 0.789
Buoyancy Factors
Factor (Kb)
107
Mud Density Buoyancy
(lb/gal) (lb/cu ft) (g/cc)
14.0 104.73 1.68 0.78614.2 106.22 1.70 0.78314.4 107.72 1.72 0.78014.6 109.22 1.75 0.77714.8 110.71 1.77 0.77415.0 112.21 1.80 0.77115.2 113.70 1.82 0.76815.4 115.20 1.84 0.76515.6 116.70 1.87 0.76215.8 118.19 1.89 0.75916.0 119.69 1.91 0.75616.2 121.18 1.94 0.75216.4 122.68 1.96 0.74916.6 124.18 1.99 0.74616.8 125.67 2.01 0.74317.0 127.17 2.03 0.74017.2 128.66 2.06 0.73717.4 130.16 2.08 0.73417.6 131.66 2.11 0.73117.8 133.15 2.13 0.72818.0 134.65 2.15 0.72518.5 138.39 2.21 0.71719.0 142.13 2.27 0.71019.5 145.87 2.33 0.70220.0 149.61 2.39 0.694
Factor (Kb)
108
A. Calculating Pressure, psi and PressureGradients, 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
MaximumAllowable
Mud Wt., ppg( ) -Mud Wt.in useppg( ) x(0.052)x(TVD, ft.)= psi
Formulas Used In Well Control and Drilling Operations
Test to determine H2S
50 ml HCl (mild hydrochloric solution)
50 ml H2O
1 gram NaASO2 (sodium arsenite)
3 drop liquid dish water soap
yellow positive sign won’t determine degree
B. Converting Pressures, psi into mud weight, ppg.
(NOTE: Anytime a pressure is to be converted tomud weight, the following formula is used.)
All of the following use the same formula:
Using the calculator, this formula is worked as follows:
(Pressure, psi) ÷ (0.052) ÷ (TVD, ft) = Mud Weight, ppg.
1. Kill Weight Mud, ppg.
(SIDPP, psi)- (0.052) - (TVD, ft) + (O.M.W.) = Kill Wt., ppg.
2. Equivalent Mud Weight = ppg. (E.M.W.)
(pressure, psi) ÷ (0.052) ÷ (TVD, ft) = E.M.W., ppg
3. Equivalent Circulating Density, ppg (E.C.D.)
AnnularPressureLoss, psi
( )÷ (0.052) ÷ (TVD, ft.) + (O.M.W.) = E.C.D., ppg
4. Maximum Allowable Mud Weight, ppg.
Leak-OffPressure
psi( ) Test
Mud Weight( )÷ (0.052) x (TVD, ft.)+ = ppg.
5. Converting Pressure Gradient, psi/ft to Mud Wt., ppg
(Pressure Gradient, PSI/ft.) ÷ (0.052) = Mud Wt., ppg.
O.M.W. (original mud weight)
SIDPP (shut in drill pipe pressure)
TVD (true vertical depth)
= Mud Weight, ppgPressure, psi
0.052 x TVD, ft.
109
REGIONAL OFFICES
NORTH AMERICA REGION
1450 Lake Robbins Dr.Suite 400The Woodlands, Texas 77380281.297.8500800.231.0283Fax: 281.297.8535
229 LukeLafayette, Louisiana 70506337.232.3098Fax: 337.261.1066
ABERDEEN
Grant PridecoSuite C, 1St Swithin RowAberdeen AB 10 6DL011.44.1224.597300Fax: 011.44.1224.589420
CANADA
Grant PridecoSuite1440, 510-5th Street SWCalgary, Alberta, Canada T2P 3S2403.571.2567Fax: 403.705.1754
CENTRAL/SOUTH AMERICA
Grant PridecoAv. Principal, Urb. Chaguaramal, Edf.Las Rocas Suites 10-aValencia, Venezuela011.58.241.824.7027Fax: 011.58.241.824.9190
www.grantprideco.comCHINAGrant PridecoSuite C411B, Beijing Lufthansa CenterNo. 50 Liangmaqiao Rd, Chaoyang DistrictBeijing, China 100016011.86.10.8454.0093/0095Fax: 011.86.10.8454.2229
CISGrant Prideco113114 Moscow, RussiaShluzovaya Nab. 6, Bldg. 1-2011.70.95.960.2404Fax: 011.70.95.960.2405
S.E. ASIA/OCEANIACitra Grant Prideco Marketing LtdNo. 11 Tuas Avenue 7Singapore 639266011.65.6861.4266Fax: 011.65.6861.0117
SOUTHERN EUROPE & AFRICA
Grant Prideco102 Franklin Roosevelt Blvd.92 500 Rueil MalmaisonParis, France011.33.147.080830Fax: 01133.147.080849
UAE/MIDDLE EAST
Grant PridecoDubai Airport Free ZoneEast Wing2, 4th Floor, Office 2E-404DubaiUnited Arab Emirates011.971.4.299.6446Fax: 011.971.4.299.6424
DISCLAIMER: Grant Prideco has produced this handbook forgeneral information only. It is not intended for design andengineering purposes. Although every effort has been made tomaintain the accuracy and reliability of its contents, Grant Pridecoin no way assumes responsibility or liability for any loss, damageor injury resulting from the use of information and data herein. Allapplications for the material described are at the user's own riskand are the user's responsibility. © 2004 Grant Prideco