grant prideco rotary shoulder handbook

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 Latest Edition, API RP 7G Latest Edition, etc., for the purpose of easier application 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 RP 7G LatestEdition. The make-up values are lower due to the combined torsional and tensile loads 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 RP 7G LatestEdition. The make-up values are lower due to the combined torsional and tensile loads 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

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Po

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Wal

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Sec

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No

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1.99

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6,02

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6,94

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6,07

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650.

280

1.81

51.

8429

1.73

46,

240

7,90

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740

138,

220

175,

080

193,

500

248,

790

2 7 /

86.

850.

217

2.44

11.

8120

2.24

28,

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2011

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135,

900

172,

140

190,

260

244,

620

10.4

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362

2.15

12.

8579

3.20

411

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20,7

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2.59

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922

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19,7

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194,

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246,

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271,

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349,

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13.3

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2.76

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5.14

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23,4

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322,

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23.

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400

19,4

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230,

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292,

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823

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29,4

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41,8

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5,36

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0.38

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156

25,7

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410,

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184

25,8

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8.54

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5.49

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51,5

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412,

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522,

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577,

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276

5.27

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15.6

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629,

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696,

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153

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106,

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534,

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676,

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747,

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19,7

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20,9

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20,9

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9.50

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13.3

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17,8

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17,4

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,320

24,8

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16,7

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23,4

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16,8

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23,5

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411

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8,60

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14.0

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14,3

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13,7

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,160

19,4

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12,9

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,340

18,0

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17,4

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213

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7,20

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8,95

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4,81

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5,49

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7,81

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Inte

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Pre

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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 13/16

4 3/44 3/4 4 3/4

5555

4 15/164 15/164 29/324 29/32

4 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 13/16

2 7/82 9/16

2 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

18,90018,80020,50018,80016,60024,50022,20019,80018,60023,40019,80021,00019,80022,20021,20020,70019,80028,80026,40022,40042,10054,40046,40061,60052,80046,20048,70045,10052,00049,90072,20058,10090,00085,70084,90081,90076,30066,90056,90079,90056,80071,60067,90063,70056,60081,200

100,300

XT24

XT26

XT29

XT31

XT38

XT39

XT40

XT46

XT50

XT54

XT55

XT57

XT69XT65

TypeConnection

BoxOD(in)

PinID(in)

XT Make-upTorque(ft-lb)


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)


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)


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• Buckinguptooljointswithtongscanputhighbend-

ingloadsinthepipe.

• Review the IADC Drilling Manual Latest Edition,orTongHeightFigureinAPIRP7GLatestEditionabout height of tool joint above slips to preventbendingpipeduringtonging.

Hmax

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

)

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.


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


· 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

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40,7

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.96

743

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00

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0.71

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411

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54

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4 3 /

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7,60

027

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40 (

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H)

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9 /16

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300

27,8

0029

.92

928

14,6

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872

9,70

037

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28.4

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0.87

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7.69

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4 11

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548,

100

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1,28

522

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53

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10.6

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869

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NC

50 (

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31,

416,

200

57,8

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.38

1,56

230

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23

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426

5 11

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100

106,

200

57.4

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63,7

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6 5 /

84

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318

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22.4

767

1 /8

6 5 /

161,

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600

118,

900

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520,

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0

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282

3.70

24

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2 1 /

884

2,40

019

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27.0

583

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38 (

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3 /4

790,

900

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771

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003

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2 1 /

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625

5.64

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490

43

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4

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620

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24,4

00

42

9 /16

0.71

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411

5.22

54

1 /2

4 3 /

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7,60

027

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NC

40 (

4 F

H)

5 1 /

42

9 /16

838,

300

27,8

0031

.51

977

14,6

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T39

4 7 /

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9,70

037

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29.9

993

022

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4 1 /

22

3 /4

0.87

59.

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7.69

85

4 11

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548,

100

40,7

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100

43,6

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.31

1,34

322

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53

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10.6

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5 1 /

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1,20

056

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NC

50 (

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5 /8

31,

416,

200

57,8

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.34

1,62

330

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HT

5088

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53,3

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5 1 /

23

1 /4

1.12

515

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14.3

426

5 11

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850,

400

75,9

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FH

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43

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1,77

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63.7

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977

41,2

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100

69,0

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5 7 /

84

0.93

814

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306

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679

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082

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XT

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100

106,

200

57.4

21,

780

63,7

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6 5 /

84

1 /2

1.06

318

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22.4

767

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6 5 /

161,

021,

600

118,

900

6 5 /

8 F

H8

4 1 /

21,

896,

100

87,9

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2,31

550

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3 3 /

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2.68

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0,90

022

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40,7

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0.71

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5.22

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1 /2

4 1 /

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20,9

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1 /4

2 13

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1,15

1,10

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49.5

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5 1 /

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NC

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3 1,

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57,8

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1,83

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11.7

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5 5 /

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5,60

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55,9

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1,71

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0.93

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100

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65.3

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027

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0.81

314

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19.2

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1 /8

6 3 /

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6,00

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2,00

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5 /8

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1,44

8,40

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38,4

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pira

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prev

ious

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to a

s 2-

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man

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(non

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ded)

.

Cen

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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




53

1 3/4 2 2 1/4 2 1/2 2 13/16



*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)



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



56


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


Recommended Minimum Make-upTorque for Rotary Shouldered Drill Collar Connections

57

2 13/16 3 3 1/4 3 1/2 3 3/4



*22,800 *22,800 *22,800*30913 *30913 *30913

*29,500 *29,500 26,500*39997 *39997 35929

32,200 30,000 26,50043657 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




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



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




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



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


9 3/4

10

9 3/4

107 5/8 H 904

10 1/4

10 1/2


11

10 3/4

8 5/8 H 904 11

11 1/4


*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


(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


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.


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


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



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


31ft (lb), 31 ft (kg)

Note 1: Refer to API Spec. 7 Latest Edition for API standard drill collar dimensions.

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


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)


Note 1: Refer to API Spec. 7 Latest Edition for API standard drill collars dimensions.

Note 2: For special configurations of drill collars, consult mfg. for reduction in weight.

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

73

Drill Collar Bending Strength Ratios

75


77


79


81


83


85


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

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


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

grant prideco rotary shoulder handbook

Documents

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makeup torque values

proper makeup torque

torque tables