rotary shoulder handbook

ROTARY SHOULDER HANDBOOK

Revised GP-7033 Handbook_Cover.indd 1Revised GP-7033 Handbook_Cover.indd 1 11/18/2010 5:33:17 PM11/18/2010 5:33:17 PM

© 2010 National Oilwell Varco

This handbook is a summary of the technical data from API Spec. 5 DP Latest Edition, API 7-1 and 7-2 Latest Edition, API RP 7G Latest Edition, etc., for the purpose of easier application in the field.

NOV® Grant Prideco® has produced this handbook for general information only. It is not intended for design and engineering purposes. Although every effort has been made to maintain the accuracy and reliability of its contents, NOV Grant Prideco in no way assumes responsibility or liability for any loss, damage or injury resulting from the use of information and data herein. All applications for the material described are at the user’s own risk and are the user’s responsibility. No expressed or implied warranty is intended.

ContentsSection I ................................... Drill Pipe

Section II .................................. Double-Shouldered Connections

SECTION III ................................ Heavy Weight Drill Pipe

SECTION IV ............................... Drill Collars

SECTION V ................................ Subs and Kellys

SECTION VI ............................... Well Control


DRILL PIPE

Drill Pipe

Proper break-in is probably the most important factor affecting the life of

the tool joint connection. Here are some recommendations to follow:

1. Proper make-up torque is determined by the connection type, size,

OD and ID and may be found in torque tables. If a torque range is

given, maximum recommended makeup torque should be applied

when possible.

2. Make up connections slowly, preferably using chain tongs. High

speed kelly spinners or the spinning chain used on initial make-up

can cause galling of the threads.

3. Tong them up to the predetermined torque using a recently

calibrated torque gauge to measure the required line-pull.

Note: Monitor breakout torque. It should be less than or no greater than make-up torque. If it is greater, the connection should be cleaned, inspected and repaired, before it is made up again.

4. Breakout, visually inspect, redope and make up two more times

before running in hole. Always use backup tongs to make and

break connections.

5. Stagger breaks on each trip so that each connection can be checked,

redoped and made up every second or third trip, depending on the

length of drill pipe and size of rig.

A new string of drill pipe deserves good surface handling equipment and

tools. Check slips and master bushings before damage occurs to the tube.

(See the IADC Drilling Manual for correct measurements).

Do not stop the downward movement of the drill stem with the slips. This

can cause crushing or necking down of the drill pipe tube. The drill pipe can

also be damaged by allowing the slips to ride the pipe on trips out of the

hole.

Good rig practices will help eliminate time consuming trips in the future,

looking for washouts or fishing for drill pipe lost in the hole. For more

information refer to the IADC Drilling Manual.

1

GP-7033 Handbook_Tabs.indd 1GP-7033 Handbook_Tabs.indd 1 11/18/2010 5:35:57 PM11/18/2010 5:35:57 PM

2

New Tool Joints

Drill PipeSize (in)

ConnectionBox OD1

(in)

Pin ID

(in)

Make-up Torque2,3

(ft-lb)

2 3/8

NC26 (IF) 3 3/8 1 3/4 3,900

OHLW 3 1/8 2 2,600

OHSW 3 1/4 1 3/4 3,700

SLH-90 3 1/4 2 2,700

WO 3 3/8 2 2,400

PAC 2 7/8 1 3/8 2,600

2 7/8

2 7/8” SH (NC26) 3 3/8 1 3/4 3,900

OHLW 3 3/4 2 7/16 3,100

OHSW 3 7/8 2 5/32 4,800

SLH-90 3 7/8 2 7/16 4,000

SLH-90 3 7/8 2 5/32 5,900

PAC 3 1/8 1 1/2 3,200

WO 4 1/8 2 7/16 3,900

X.H. 4 1/4 1 7/8 7,000

NC31 (IF) 4 1/8 2 1/8 6,400

NC31 (IF) 4 1/8 2 7,100

NC31 (IF) 4 3/8 1 5/8 9,000

3 1/2

3 1/2 SH (NC31) 4 1/8 2 1/8 6,400

SLH-90 4 5/8 3 6,500

SLH-90 4 5/8 2 11/16 9,500

OHLW 4 3/4 3 6,500

OHSW 4 3/4 2 11/16 9,300

NC38 (WO) 4 3/4 3 6,800

NC38 (IF) 4 3/4 2 11/16 9,700

NC38 (IF) 5 2 9/16 10,700

NC38 (IF) 5 2 7/16 11,700

NC38 (IF) 5 2 1/8 14,000

NC40 (4” FH) 5 1/4 2 9/16 14,600

NC40 (4” FH) 5 3/8 2 7/16 15,600

NC40 (4” FH) 5 1/2 2 1/4 17,100

4

SH (3 1/2”XH) 4 5/8 2 9/16 8,100

OHLW 5 1/4 3 15/32 11,900

OHSW 5 1/2 3 1/4 14,700

NC40 (4” FH) 5 1/4 2 13/16 12,400

NC40 (4” FH) 5 1/4 2 11/16 13,500

NC40 (4” FH) 5 1/2 2 7/16 15,600

NC40 (4” FH) 5 1/2 2 7/16 15,600

NC46 (WO) 5 3/4 3 7/16 15,200

NC46 (IF) 6 3 1/4 17,600

NC46 (IF) 6 3 20,500

NC46 (IF) 6 3 20,500

NC46 (IF) 6 3 1/4 17,600

NC46 (IF) 6 3 20,500

NC46 (IF) 6 2 5/8 24,400

NC46 (IF) 6 2 7/8 21,900

Torque Chart-Drill Pipe Tool Joint

Notes:1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on Slim Hole

(S.H.) tool joints due to special service requirements.2. Make-up torque values may be lower than those published in API RP7G Latest Edition. The make-up

values are lower due to the combined torsional and tensile loads found in service conditions.


3

Used Tool JointsPremium Class 2

Box OD1 (in)

Make-UpTorque2,3

(ft-lb)

Box OD1 (in)

Make-UpTorque2,3

(ft-lb)

3 1/4 3,000 3 3/16 2,500

3 1/16 2,300 3 1/32 2,100

3 1,800 2 31/32 1,600

2 31/32 2,000 3 31/32 2,000

3 1/16 2,000 3 1,500

2 25/32 2,500 2 23/32 2,100

3 3/8 3,900 3 5/16 3,600

3 1/2 3,100 3 7/16 2,700

3 19/32 4,300 3 17/32 3,600

3 17/32 3,800 3 17/32 3,800

3 19/32 4,500 3 17/32 3,800

3 1/8 3,500 3 1/16 3,500

3 5/8 3,200 3 9/16 2,500

3 23/32 4,400 3 21/32 3,700

3 11/16 3,200 3 21/32 2,800

3 29/32 5,700 3 13/16 4,600

4 1/16 7,700 3 31/32 6,500

4 6,400 3 29/32 5,700

4 3/16 5,500 4 1/8 4,500

4 3/8 8,800 4 9/32 7,100

4 9/32 5,500 4 7/32 4,600

4 3/8 7,000 4 5/16 6,000

4 3/8 5,300 4 11/32 4,800

4 3/8 5,300 4 11/32 4,800

4 19/32 8,800 4 1/2 7,300

4 21/32 9,900 4 9/16 8,300

4 23/32 10,900 4 5/8 9,300

4 15/32 11,400 4 13/32 9,000

5 12,600 4 7/8 10,200

5 3/32 14,400 4 15/16 11,400

4 7/16 8,800 4 11/32 7,400

4 31/32 7,500 4 29/32 6,200

5 1/32 8,800 4 31/32 7,500

4 13/16 9,000 4 23/32 7,300

4 15/16 11,400 4 13/16 9,000

5 12,600 4 7/8 10,200

5 12,600 4 7/8 10,200

5 7/32 7,900 5 5/32 6,500

5 5/32 10,000 5 7/32 7,900

5 7/16 12,800 5 5/16 10,000

5 15/32 13,600 5 3/8 11,400

5 9/32 9,200 5 3/16 7,200

5 9/16 15,800 5 7/16 12,800

5 5/8 17,300 5 1/2 14,300

5 5/8 17,300 5 1/2 14,300

Notes (cont): 3. Make-up torque is based on the use of 40% to 50% by weight of finely powdered metallic zinc

applied to all threads and shoulders.

TAB 1 RSHandbook_Drill Pipe.indd 3TAB 1 RSHandbook_Drill Pipe.indd 3 11/18/2010 5:36:37 PM11/18/2010 5:36:37 PM

4

Torque Chart-Drill Pipe Tool Joint (cont.)

New Tool Joints

Drill PipeSize(in)

ConnectionBox OD1

(in)

Pin ID

(in)

Make-upTorque2,3

(ft-lb)

4 1/2

OHSW 5 7/8 3 3/4 14,600

FH 6 3 17,600

FH 6 2 3/4 20,100

FH 6 2 1/2 22,300

NC46 (XH) 6 1/4 3 1/4 17,600

NC46 (XH) 6 1/4 3 20,500

NC46 (XH) 6 1/4 2 3/4 23,200

NC46 (XH) 6 1/4 2 1/2 25,600

NC50 (IF) 6 3/8 3 3/4 19,800

NC50 (IF) 6 3/8 3 3/4 19,800

NC50 (IF) 6 3/8 3 5/8 21,600

NC50 (IF) 6 3/8 3 1/2 23,400

NC50 (IF) 6 3/8 2 7/8 30,300

5

NC50 (XH) 6 3/8 33/4 19,800

NC50 (XH) 6 3/8 3 1/2 23,400

NC50 (XH) 6 1/2 3 1/4 26,800

NC50 (XH) 6 1/2 3 30,000

NC50 (XH) 6 5/8 2 3/4 32,900

5 1/2” FH 7 3 1/2 37,400

5 1/2” FH 7 1/4 3 1/2 37,400

5 1/2” FH 7 1/4 3 1/4 41,200

5 1/2

FH 7 4 29,200

FH 7 4 29,200

FH 7 3 3/4 33,400

FH 7 1/4 3 1/2 37,400

FH 7 1/4 3 1/2 37,400

FH 7 1/4 3 1/2 37,400

FH 7 1/2 3 44,600

FH 7 1/2 3 44,600

6 5/8

FH 8 5 38,400

FH 8 5 38,400

FH 8 5 38,400

FH 8 1/4 4 3/4 44,600

FH 8 1/4 4 3/4 44,600

FH 8 1/4 4 3/4 44,600

FH 8 1/2 4 1/4 56,100

FH 8 1/2 4 1/4 56,100

Notes:1. The use of outside diameters (OD) smaller than those listed in the table may be acceptable on

Slim Hole (SH) tool joints due to special service requirements.2. Make-up torque values may be lower than those published in API RP7G Latest Edition. The make-up

values are lower due to the combined torsional and tensile loads found in service conditions.3. Make-up torque is based on the use of 40% to 50% by weight of finely powdered metallic zinc applied to

all threads and shoulders.

5

Used Tool JointsPremium Class 2

BoxOD1

(in)

Make-UpTorque2,3

(ft-lb)

BoxOD1

(in)

Make-upTorque2,3

(ft-lb)

5 15/32 12,300 5 3/8 10,000

5 3/8 12,100 5 9/32 10,100

5 9/16 16,400 5 7/16 13,500

5 5/8 17,800 5 15/32 14,200

5 13/32 12,100 5 5/16 9,900

5 19/32 16,500 5 15/32 13,500

5 25/32 21,200 5 5/8 17,300

5 23/32 19,600 5 9/16 15,800

5 29/32 16,600 5 25/32 13,200

5 23/32 11,600 5 21/32 10,000

5 13/16 14,100 5 23/32 11,600

5 15/16 17,500 5 27/32 14,900

6 7/32 25,500 6 1/16 21,000

5 7/8 15,800 5 25/32 13,300

6 1/32 20,200 5 29/32 16,700

6 3/32 21,900 5 31/32 18,400

6 3/16 24,700 6 1/32 22,000

6 5/16 28,400 6 3/16 24,600

6 21/32 25,500 6 1/2 20,200

6 23/32 27,700 6 9/16 22,300

6 15/16 35,500 6 3/4 28,800

6 17/32 21,300 6 7/16 18,200

6 9/16 22,300 6 15/32 19,200

6 5/8 24,500 6 1/2 20,300

6 23/32 27,650 6 19/32 23,350

6 25/32 29,900 6 5/8 24,500

6 25/32 29,900 6 11/16 26,560

7 1/32 39,000 6 27/32 32,100

7 1/32 39,000 6 7/8 33,200

7 7/16 26,800 7 3/8 24,100

7 1/2 29,500 7 13/32 25,500

7 5/8 35,100 7 1/2 29,500

7 11/16 38,000 7 9/16 32,300

7 11/16 38,000 7 19/32 33,700

7 3/4 40,900 7 21/32 36,500

7 29/32 48,200 7 25/32 42,300

8 52,700 7 27/32 45,200


6

Performance Properties of Seamless Drill PipeNe

w Dr

ill P

ipe D

imen

siona

l, To

rsio

nal a

nd Te

nsile

Dat

a

Size OD (in

)

Nom

inal

Wei

ght

(lb/f

t)

Wal

lTh

ick-

ness

(in)

ID (in)

Cros

s Se

ctio

nal

Area

of

Pip

e(sq

in)

Pola

rSe

ctio

nal

Mod

ulus

Z(cu

in)

Tors

iona

l Yie

ld St

reng

th (f

t-lb)

Tens

ile Yi

eld S

treng

th (l

b)

E75

X95

G105

S135

E75

X95

G105

S135

2 3/

84.

856.

650.

190

0.28

01.

995

1.81

51.

3042

1.84

291.

320

1.73

44,

760

6,24

06,

020

7,90

06,

060

8,74

0– –

97,8

2013

8,22

012

3,90

017

5,08

013

6,94

019

3,50

017

6,07

024

8,79

0

2 7/

86.

8510

.40

0.21

70.

362

2.44

12.

151

1.81

202.

8579

2.24

23.

204

8,07

011

,530

10,2

2014

,610

11,3

0016

,150

–20

,760

135,

900

214,

340

172,

140

271,

500

190,

260

300,

080

244,

620

385,

820

3 1/

29.

5013

.30

15.5

0

0.25

40.

368

0.44

9

2.99

22.

764

2.60

2

2.59

023.

6209

4.30

37

3.92

25.

144

5.84

6

14,1

2018

,520

21,0

50

17,8

9023

,460

26,6

60

19,7

7025

,930

29,4

70

25,4

2033

,330

37,8

90

194,

260

271,

570

322,

780

246,

070

343,

990

408,

850

271,

970

380,

190

451,

890

349,

680

488,

820

581,

000

411

.85

14.0

015

.70

0.26

20.

330

0.38

0

3.47

63.

340

3.24

0

3.07

673.

8048

4.32

16

5.40

06.

458

7.15

6

19,4

4023

,250

25,7

60

24,6

2029

,450

32,6

30

27,2

2032

,550

36,0

70

34,9

9041

,840

46,3

80

230,

750

285,

360

324,

150

292,

290

361,

460

410,

590

323,

050

399,

500

453,

810

415,

360

513,

650

583,

420

4 1/

213

.75

16.6

020

.00

0.27

10.

337

0.43

0

3.95

83.

826

3.64

0

3.60

044.

4074

5.49

81

7.18

48.

542

10.2

32

25,8

6030

,750

36,8

40

32,7

6038

,950

46,6

60

36,2

1043

,050

51,5

70

46,5

5055

,350

66,3

00

270,

030

330,

560

412,

360

342,

040

418,

700

522,

320

378,

050

462,

780

577,

300

486,

060

595,

000

742,

240

519

.50

25.6

00.

362

0.50

04.

276

4.00

05.

2746

7.06

8611

.416

14.4

9041

,090

52,1

6052

,050

66,0

7057

,530

73,0

3073

,970

93,9

0039

5,60

053

0,14

050

1,09

067

1,52

055

3,83

074

2,20

071

2,07

095

4,26

0

5 1/

221

.90

24.7

00.

361

0.41

54.

778

4.67

05.

8282

6.62

9614

.062

15.6

8850

,620

56,4

7064

,120

71,5

3070

,870

79,0

6091

,120

101,

650

437,

120

497,

220

553,

680

629,

810

611,

960

696,

110

786,

810

895,

000

5 7/

8 23

.40

26.3

0 0

.361

0.

415

5.15

3 5.

045

6.25

357.

1185

16.2

5118

.165

58,6

0065

,500

74,2

00

83,0

0082

,000

91

,700

105,

500

117,

900

469,

000

533,

900

594,

100

676,

300

656,

600

747,

400

844,

200

961,

000

6 5/

825

.20

27.7

00.

330

0.36

25.

965

5.90

16.

5262

7.12

2619

.572

21.1

5670

,550

89,3

6098

,770

106,

800

127,

044

137,

300

489,

460

534,

200

619,

990

676,

700

685,

250

747,

900

881,

044

961,

600

76,3

0096

,600


7

New Drill Pipe Collapse and Internal Pressure Data

Size OD (in

)

Nom

inal

Wei

ght

(lb)

Mat

eria

l Gra

de

Colla

pse P

ress

ure,

(psi)

Inte

rnal

Pre

ssur

e, (p

si)

E75

X95

G105

S135

E75

X95

G105

S135

2 3/

84.

856.

6511

,040

15,6

0013

,980

19,7

6015

,460

21,8

4019

,070

28,0

8010

,500

15,4

7013

,300

19,6

0014

,700

21,6

6018

,900

27,8

50

2 7/

86.

8510

.40

10,4

7016

,510

12,9

3020

,910

14,0

1023

,110

17,0

6029

,720

9,91

016

,530

12,5

5020

,930

13,8

7023

,140

17,8

3029

,750

3 1/

29.

5013

.30

15.5

0

10,0

4014

,110

16,7

70

12,0

6017

,880

21,2

50

13,0

5019

,760

23,4

80

15,7

8025

,400

30,1

90

9,52

013

,800

16,8

40

12,0

7017

,480

21,3

30

13,3

4019

,320

23,5

70

17,1

5024

,840

30,3

10

411

.85

14.0

015

.70

8,41

011

,350

12,9

00

9,96

014

,380

16,3

40

10,7

0015

,900

18,0

50

12,6

5020

,170

23,2

10

8,60

010

,830

12,4

70

10,8

9013

,720

15,7

90

12,0

4015

,160

17,4

60

15,4

8019

,490

22,4

40

4 1/

213

.75

16.6

020

.00

7,20

010

,390

12,9

60

8,40

012

,750

16,4

20

8,95

013

,820

18,1

50

10,3

1016

,800

23,3

30

7,90

09,

830

12,5

40

10,0

1012

,450

15,8

90

11,0

7013

,760

17,5

60

14,2

3017

,690

22,5

80

519

.50

25.6

010

,000

13,5

0012

,010

17,1

0012

,990

18,9

0015

,700

24,3

009,

500

13,1

2012

,040

16,6

2013

,300

18,3

8017

,110

23,6

20

5 1/

221

.90

24.7

08,

440

10,4

6010

,000

12,9

2010

,740

14,0

0012

,710

17,0

508,

610

9,90

010

,910

12,5

4012

,060

13,8

6015

,510

17,8

30

5 7/

823

.40

26.3

07,

450

9,56

0 8

,770

11,5

009,

360

12,4

1010

,820

14,8

908,

060

9,27

010

,220

11,7

4011

,290

12,9

8014

,520

16,6

90

6 5/

825

.20

27.7

04,

810

5,89

05,

310

6,75

05,

490

7,10

06,

040

7,81

06,

540

7,17

08,

280

9,08

09,

150

10,0

4011

,770

12,9

10

8

Tool Joint Bevel Diameters

Type Size (in) OD (in) Bev. Dia. (in)

Internal Flush

&Numbered

Connections

2 3/8 & NC26 3 3/8 3 17/64

2 7/8 & NC31 4 1/8 3 61/64

3 1/2 & NC38 4 3/4 4 37/64

3 1/2 & NC38 5 4 37/64

NC40 5 1/2 5 1/64

4 & NC46 6 5 23/32

4 & NC46 6 1/4 5 23/32

4 1/2 & NC50 6 1/8 6 1/16

4 1/2 & NC50 6 1/4 6 1/16

4 1/2 & NC50 6 3/8 6 1/16

4 1/2 & NC50 6 1/2 6 1/16

4 1/2 & NC50 6 5/8 6 1/16

NC56 7 6 47/64

Full Hole&

NumberedConnections

3 1/2 4 5/8 4 31/64

4 & NC40 5 1/4 5 1/64

4 1/2 6 5 23/32

5 1/2 7 6 23/32

5 1/2 7 1/4 6 23/32

5 1/2 7 1/2 7 3/32

Xtra Hole &Numbered

Connections

3 1/2 4 3/4 4 17/32

4 1/2 & NC46 6 5 23/32

5 & NC50 6 1/4 5 59/64

H-904 5 1/2 5 17/64

4 1/2 6 5 23/32

SlimlineH-90

2 3/8 3 1/4 3 1/8

2 7/8 3 7/8 3 23/32

3 1/2 4 5/8 4 7/16

Slimhole &

NumberedConnections

2 3/8 2 7/8 2 25/32

2 7/8 & NC26 3 3/8 3 17/64

3 1/2 & NC31 4 1/8 3 61/64

4 4 1/2 4 11/32

4 4 5/8 4 11/32

4 1/2 & NC38 5 4 37/64


9

Decimal and Millimeter Equivalents

1 mm = 0.03937 inch0.001 inch = 0.0254 mm

Fraction Decimal mm

1/64 0.015625 0.397

1/32 0.03125 0.794

3/64 0.046875 1.191

1/16 0.0625 1.588

5/64 0.078125 1.984

3/32 0.09375 2.381

7/64 0.109375 2.778

1/8 0.1250 3.175

9/64 0.140625 3.572

5/32 0.15625 3.969

11/64 0.171875 4.366

3/16 0.1875 4.763

13/64 0.203125 5.159

7/32 0.21875 5.556

15/64 0.234375 5.953

1/4 0.2500 6.350

17/64 0.265625 6.747

9/32 0.28125 7.144

19/64 0.296875 7.541

5/16 0.3125 7.938

21/64 0.328125 8.334

11/32 0.34375 8.731

23/64 0.359375 9.128

3/8 0.3750 9.525

25/64 0.390625 9.922

13/32 0.40625 10.319

27/64 0.421875 10.716

7/16 0.4375 11.113

29/64 0.453125 11.509

15/32 0.46875 11.906

31/64 0.484375 12.303

1/2 0.5000 12.700

Fraction Decimal mm

33/64 0.515625 13.097

17/32 0.53125 13.494

35/64 0.546875 13.891

9/16 0.5625 14.288

37/64 0.578125 14.684

19/32 0.59375 15.081

39/64 0.609375 15.478

5/8 0.6250 15.875

41/64 0.640625 16.272

21/32 0.65625 16.669

43/64 0.671875 17.066

11/16 0.6875 17.463

45/64 0.703125 17.859

23/32 0.71875 18.256

47/64 0.734375 18.653

3/4 0.7500 19.050

49/64 0.765625 19.447

25/32 0.78125 19.844

51/64 0.796875 20.241

13/16 0.8125 20.638

53/64 0.828125 21.034

27/32 0.84375 21.431

55/64 0.859375 21.828

7/8 0.8750 22.225

57/64 0.890625 22.622

29/32 0.90625 23.019

59/64 0.921875 23.416

15/16 0.9375 23.813

61/64 0.953125 24.209

31/32 0.96875 24.606

63/64 0.984375 25.003

1 1.000 25.400


10

Conversion of Customary Units to SI/Metric Units

BasicUnit

CustomaryUnits

(Abbreviation)

SI/MetricUnits

(Abbreviation)

ConversionCustomary to

SI/MetricMultiply by

Length in mm 25.4

Area sq in mm2 645.16

Volume, capacity

cu ft

U.K. gal

U.S. gal

m3

L

L

0.028317

4.546092

3.785412

Plane angle deg (0) rad 0.017453

Time min S 60

Mass lbm kg 0.453592

Temperature (traditional) °F °C(°F-32)

1.8

Pressure

lbf/in2(psi)

N/m2

at (kp/cm2)

bar

bar

Pa

bar

Pa

0.068947

1.

1.0197

105

Density (liquids)

lbm/U.S. gal

lbm/U.K. gal

lbm/ft

kg/m3

kg/m3

kg/m3

119.8264

99.77633

16.01846

Density (solids) lbm/ft3 kg/m3 16.01846

Throughput (mass basis) lbm/hr kg/h 0.453592

Throughput (volume basis)

bbl/D

ft3/D

U.K. gal/min

U.S. gal/min

m3/h

m3/h

L/min

L/min

0.006624

0.001179

4.546092

3.785412

Flow rate (volume basis)

U.K. gal/min

U.S. gal/min

ft3/min

L/min

L/min

m3/min

4.546092

3.785412

0.028314

Energy work

Btu

ft-lbf

lbf-ft

K N-m

kWh

kJ

kJ

kJ

0.000293

0.001356

0.001356

1.

Power

hydraulic horse

power-hhp

hp (electric)

Btu/hr

kW

kW

W

0.746043

0.746

0.293071

Fuel consumptionmile/U.S. gal

mile/U.K. gal

km/L

km/L

0.425144

0.354066

Velocity (linear) speedft/min

in/s

m/s

mm/s

0.005080

25.4

Rotational frequencyrev/s

rev/min

rev/s

rev/s

1.0

0.016666

Weight/length lb/ft kg/m 1.488164

Forcelbf

kg-m/sec2

N

N

4.448222

1.

Bending moment torque lbf-ft Nm 1.355818

Section modulus cu in mm3 2831685

Stress kgf/mm2

lbf/in2 (psi)

N/mm2

N/mm2

9.806650

0.006895


DO

UBLE-

SHO

ULD

EREDCO

NN

ECTION

S

Pin Base

Pin base extends in

spring-like manner

when joint is bucked

up to recommended

make-up torque.

Secondary Shoulder

When joint is hand

tight, secondary

shoulders do not

contact. When joint

is bucked up to

recommended

make-up torque,

they do contact.

Primary Shoulder

Provides seal and

preload just as on

conventional tool

joint.

Box Counterbore Section

Box counterbore

section compresses

in spring-like

manner when joint

is bucked up to

recommended

make-up torque.

Pin Nose

Drill Pipe with Double-Shouldered Connections

Box

Weld

Pipe

PinExternal Upset

Tool Joint

Elevator ShoulderInternal Upset

Internal Coating

Hardbanding

11


Double-shouldered connections offered by NOV Grant Prideco include:

• HI TORQUE® (HT™) – First generation double-shouldered connection

providing approximately 40% more torque capacity than API

connections of equivalent dimensions. Not interchangeable with

API connections.

• eXtreme® Torque (XT®) – Second generation double-shouldered

connection providing approximately 65% more torque capacity than

API connections of equivalent dimensions. Not interchangeable with

API connections. Primary differences exist between HT and XT con-

nections are XT has a shallow taper and a fatigue-resistant thread

form.

– eXtreme® Torque with Metal-to-Metal Seal (XT-M™) –

Industry's first gas-tight pressure rated rotary-shouldered

connection with a metal-to-metal seal. The radial seal provides

a pressure rating of 15,000 psi internal, and 10,000 psi external.

This provides torque capacity similar to that of XT connections.

Not interchangeable with API connections.

The figure below illustrates the taper difference between HT® and XT®

connections.

• Grant Prideco Double Shoulder® (GPDS®) – Double-shouldered

connection that is interchangeable with API connections and

provides approximately 40% more torque capacity than API

connections of equivalent dimensions.

XT

HT

Types of Grant Prideco Double-Shouldered Connections

12

13

• TurboTorque® – Third generation double shoulder connection

providing approximately 80% more torque capacity than API

connections of equivalent dimensions, and 10-15% over XT®.

Not interchangeable with API connections. Primary benefits

for TurboTorque connections include: it saves time, cuts costs;

increases torque capacity; optimizes hydraulics; improves

clearance and fishability; reduces risk of failure; and extends life

of the connection itself.

– TurboTorque-M™ with Metal-To-Metal Seal – Gas-tight

pressure-rated rotary shoulder connection. The radial seal

provides a pressure rating of 20,000 psi internal, and

10,000 psi external. Torque capacity is similar to that of

TurboTorque connections. Not interchangeable with API

connections.

Starting Thread

Starting Thread 2

Starting Thread 1

XT®57≈ 13 revolutions

TurboTorque® 585≈ 4 revolutions

TurboTorque connections are the first in the industry to provide a Turbo-MUT™. Also known as "torque-on-demand", Turbo-MUT provides an additional 8% of torque capacity for those unusual drilling situations when additional torque is required. Most of the testing and design validation for the TurboTorque family were conducted on connections made up to the Turbo-MUT value.

TAB 2 RSHandbook_DSC.indd Sec1:13TAB 2 RSHandbook_DSC.indd Sec1:13 11/18/2010 5:37:04 PM11/18/2010 5:37:04 PM

14

TurboTorque® Tool Joint Make-up Torque Chart

Note: 1. Applies to drill pipe and heavy weight drill pipe tool joints. See page 13.

TypeConnection

BoxOD(in)

PinID

(in)

MinimumMUT

(ft-lb)

RecommendedMUT

(ft-lb)

Turbo-MUT™ (ft-lb)1

TurboTorque 3804 3/4

4 13/162 11/16

2 1/216,80019,900

20,20023,900

21,90025,900

TurboTorque 390 4 7/8 2 11/16 19,600 23,500 25,500

TurboTorque 420 5 1/4 2 15/16 23,700 28,400 30,800

TurboTorque 435 5 3/8 3 1/8 24,700 29,600 32,100

TurboTorque 4856

6 1/83 9/163 1/4

31,50039,700

37,80047,600

40,90051,600

TurboTorque 500 6 1/4 3 1/2 38,900 46,600 50,500

TurboTorque 5256 1/26 5/8

3 7/83 9/16

38,20048,000

45,80057,600

49,60062,400

TurboTorque 550 6 5/8 4 1/4 39,100 46,900 50,900

TurboTorque 5857

7 1/84 1/2

4 5/1647,80055,500

57,30066,600

62,10072,200

TurboTorque 690 8 1/4 5 1/2 63,100 75,800 82,100

15

TurboTorque-M™ Tool Joint Make-up Torque Chart

TypeConnection

BoxOD(in)

PinID

(in)

MinimumMUT

(ft-lb)

RecommendedMUT

(ft-lb)

Turbo-MUT™ (ft-lb)1

TurboTorque-M 3804 3/4

4 13/162 11/16

2 1/214,80017,900

17,70021,400

19,20023,200

TurboTorque-M 390 4 7/8 2 11/16 17,400 20,900 22,700

TurboTorque-M 420 5 1/4 2 15/16 21,200 25,500 27,600

TurboTorque-M 435 5 3/8 3 1/8 22,000 26,400 28,600

TurboTorque-M 4856

6 1/83 9/163 1/4

28,20036,500

33,90043,800

36,70047,400

TurboTorque-M 500 6 1/4 3 1/2 35,400 42,500 46,000

TurboTorque-M 5256 1/26 5/8

3 7/83 9/16

34,40044,200

41,20053,100

44,70057,500

TurboTorque-M 550 6 5/8 4 1/4 43,900 41,800 45,300

TurboTorque-M 5857

7 1/84 1/2

4 5/1643,00050,800

51,60060,900

55,90066,000

TurboTorque-M 690 8 1/4 5 1/2 58,800 70,600 76,500

TurboTorque-M 710 8 1/2 5 5/8 65,400 78,500 85,000

Note: 1. Applies to drill pipe and heavy weight drill pipe tool joints. See page 13.


16

XT® Tool Joint Make-up Torque Chart

Note: Applies to drill pipe and heavy weight drill pipe tool joints.

Type Connection

Box OD(in)

Pin ID (in)

XT® Recommended MUT

(ft-lb)

XT24 3 1/8 1 1/2 5,700

XT26

3 1/2

3 1/2

3 1/2

1 3/4

1 1/2

1 1/4

6,900

8,900

9,900

XT29 3 3/4 2 9,000

XT31

4 1/8

4 1/8

4

4

2

1 7/8

2

2 1/8

12,700

14,000

12,200

11,200

XT38

4 7/8

4 7/8

4 3/4

4 3/4

4 3/4

2 9/16

2 7/16

2 11/16

2 9/16

2 7/16

18,900

20,900

16,600

18,800

20,500

XT39

4 7/8

4 7/8

4 7/8

5

5

5

5

4 7/8

2 9/16

2 3/4

2 13/16

2 7/8

2 13/16

2 11/16

2 9/16

2 11/16

22,200

20,700

19,800

18,600

19,800

22,200

24,500

21,200

XT405 1/4

5 1/4

3

2 13/16

22,400

26,400

XT435 3/4

5 3/8

2 3/4

3

34,000

28,300

XT46 6 1/4 3 1/4 42,100

XT50

6 5/8

6 5/8

6 1/2

6 3/8

6 3/8

3 3/4

3 1/2

3 3/4

3 3/4

3 1/2

46,400

54,400

46,200

45,100

48,700

XT546 3/4

6 5/8

4

4

52,000

49,900

XT557 3/8

7

3 5/8

4

72,200

58,100

XT57

7 1/4

7 1/4

7 1/4

7 1/4

7 1/8

7

7

7

7

3 3/4

3 1/2

3 1/4

3 3/16

3 1/4

4 1/4

4

3 3/4

3 1/2

76,300

81,500

84,900

85,700

79,900

56,600

63,700

67,900

71,600

XT65 8 5 81,200

XT69 8 1/2 5 1/4 100,300


17


XT-M™ Tool Joint Make-up Torque Chart

Type Connection

Box OD(in)

Pin ID(in)

XT-M™ Recommended MUT

(ft-lb)

XT-M26 3 3/8 1 3/4 5,000

XT-M31

4

4

3 7/8

2

2 1/8

2 1/8

10,800

9,700

8,500

XT-M34 4 1/4 2 9/16 9,700

XT-M384 3/4

4 3/4

2 9/16

2 11/16

16,700

14,500

XT-M39

5

5

5

4 7/8

2 7/16

2 9/16

2 13/16

2 11/16

23,300

22,300

17,700

18,900

XT-M40 5 1/4 2 11/16 26,200

XT-M435 1/4

5 1/4

3

3 1/4

23,500

19,500

XT-M46 6 1/4 3 45,100

XT-M50

6 5/8

6 1/2

6 1/4

6 1/4

3 1/2

3 3/4

3 1/2

3 5/8

50,300

42,100

40,700

38,900

XT-M54 6 3/8 4 41,500

XT-M57

7 1/4

7

7

7

4 1/4

4

4 1/8

4 1/4

51,900

58,700

56,500

51,600

XT-M65 8 5 74,600

XT-M69 8 1/2 5 1/4 92,900


18

GPDS® Tool Joint Make-up Torque Chart


Type Connection

Box OD(in)

Pin ID(in)

GPDS®Recommended MUT

(ft-lb)

GPDS26

3 3/8

3 1/2

3 1/2

1 3/4

1 11/16

1 5/8

5,200

5,800

6,300

GPDS314 1/8

4 1/8

2

1 7/8

10,300

11,600

GPDS38

5

5

5

4 7/8

4 7/8

2 7/16

2 9/16

2 1/4

2 9/16

2 7/16

17,500

15,500

20,300

15,400

17,400

GPDS40

5 1/2

5 3/8

5 1/4

5 1/4

5 1/4

5 1/4

2 7/16

2 1/2

2 11/16

2 5/8

2 9/16

2 1/2

24,200

23,000

19,600

20,800

21,900

22,900

GPDS46

6

6

6

6

6

6

3 1/4

3 3/16

3 1/8

3

2 15/16

2 3/4

25,700

27,300

28,800

31,800

33,200

37,200

GPDS50

6 5/8

6 5/8

6 5/8

6 1/2

6 1/2

6 1/2

2 3/4

3

3 1/4

3 1/4

3 1/2

3 3/4

54,400

49,700

43,300

43,100

36,100

28,500

GPDS55

7 1/4

7 1/8

7

7

7

3 3/4

3 3/4

3 1/2

3 3/4

4

53,800

53,600

53,900

50,300

44,500

GPDS65

8 1/4

8 1/2

8

4 3/4

4 1/4

4 7/8

70,400

94,800

63,600


19


HT® Tool Joint Make-up Torque Chart

Type Connection

Box OD(in)

Pin ID(in)

HT®Recommended MUT

(ft-lb)

2 3/8 HTSLH903 1/8

3 1/8

1.975

1 3/4

4,600

5,600

2 7/8 HTPAC3 1/8

3 1/8

1 1/2

1 3/8

5,100

5,900

HT26

3 5/8

3 5/8

3 5/8

3 1/2

3 3/8

1 1/2

1 3/8

1 1/4

1 1/2

1 3/4

7,900

8,700

9,200

7,300

5,200

HT31

4 1/4

4 1/8

4 1/8

4 1/8

1 3/4

2 1/8

2

1 7/8

14,000

10,000

11,300

11,900

HT38

5

5

4 3/4

4 3/4

4 3/4

4 7/8

2 9/16

2 7/16

2 11/16

2 9/16

2 7/16

2 9/16

17,700

19,800

15,200

16,100

17,000

17,700

HT40

5 1/8

5 1/8

5 1/2

5 1/4

5 1/4

2 9/16

2 11/16

2 9/16

2 13/16

2 11/16

21,100

20,100

24,000

19,200

21,500

HT466 1/4

6 1/4

3 1/4

3

28,500

34,600

HT50

6 5/8

6 5/8

6 5/8

6 5/8

6 3/8

6 1/4

3 3/4

3 1/2

3 1/4

3

3 1/2

3 3/4

32,000

39,700

46,800

53,300

39,400

31,600

HT55

7 1/2

7 3/8

7 1/4

7 1/4

7 1/4

7 1/4

7 1/4

7 1/8

7 1/8

7 1/8

7 1/8

7

7

3 3/16

3 3/8

4

3 3/4

3 1/2

3 1/4

3

4

3 7/8

3 1/2

3 1/4

4

3 3/4

73,800

68,000

46,700

55,600

63,900

69,000

72,000

46,500

51,100

61,000

64,200

46,300

52,600

HT65

8 1/2

8 1/2

8 1/4

8

5

4 1/4

4 13/16

5

60,500

97,800

70,100

59,800


20

The following sections provide general guidelines for running and handling double-shouldered connections. Connection-specific procedures are available directly from NOV Grant Prideco and can be downloaded from: www.nov.com/grantprideco

Tool Joint Break-inMost drill pipe connections are broken in during manufacture. The

following break-in procedure is recommended for connections which

have not been broken in during manufacture.

Step 1: Make up the joints to the maximum recommended make-up

torque, and then break them out. If the break-out torque is

less than the make-up torque, the joints do not have to be

separated.

Step 2: Make up the joints again to the same make-up torque and

break them out. Separate the pin and box and reapply thread

compound.

Step 3: Make up the joints again to the same make-up torque and they

are ready for service.

Note: The break-out torque should be less than the make-up torque. If the break-out torque is more than the make-up torque, separate the joints and inspect them for damage.

Picking Up Pipe with Double-Shouldered Connections for the First Time• Visually examine the thread protectors for damage such as dents or

crushing. If any thread protectors are damaged, inspect the threads on that joint for damage.

• If the joints were shipped to the rig with rust preventive on the threads, it must be removed. Use soap and water, steam or a degreasing solvent such as Varsol. No residue should remain on the threads after cleaning.

• If the joints were shipped to the rig with thread compound, it is not necessary to remove the thread compound unless a problem is suspected.

• Inspect the threads for damage or for foreign material.

• Before the joints are put in service, the threads, the primary make-up shoulders and secondary make-up shoulders must be coated with a good quality rotary-shouldered connection thread compound.


21

Special Considerations When Running XT®, TurboTorque®, XT-M™ and TurboTorque-M™ Connections

• Check to ensure the counterbalance on the top drive is working properly and provides a minimum amount of weight applied to the connection during stabbing and make-up.

• Ensure the bore through the top drive bell stabbing guide (top drive flipper) is no more than ½” larger in diameter than the box tool joint diameter.

• Because of the shallow taper, connections do not stab as deep into the box as API connections. Alignment of the pin to the box when stabbing and spinning up is more critical for shallow taper connec-tions.

• Proper alignment, along with slow initial make-up of the starting threads is necessary with XT and XT-M connections. Use chain tongs or slow speed spinners when spinning in the starting threads. High-speed spinners may be used after the starting threads are engaged.

• Minor thread damage may occur within the starting threads. This is not detrimental to the connection and protruding metal should be removed with a soft grinding wheel or a file.

• A stabbing guide is required when running XT, XT-M and TurboTorque-M™ connections and alignment should be verified before spinning up. A stabbing guide is recommended for HT®, GPDS®, and TurboTorque connections.


22

Application of Thread Compound to Double-Shouldered Connections• All contacting surfaces – the threads, the primary shoulders, second-

ary shoulders and 15° metal seal (XT-M™, TurboTorque-M™) – must be coated with a good quality rotary-shouldered connection thread compound. Copper-based thread compounds are recommended because of the anti-galling resistance, the repeatability of frictional characteristics and the generally higher friction coefficient (yielding less stress in the connection for equivalent MUTs). Standard API thread compounds are sufficient.

• Some drilling fluids or drilling fluid additives may affect the frictional properties of the tool joint and thread compound. If this is the case, rinse the drilling fluid off the connections before applying thread compound.

• Remove drilling fluid from the secondary shoulder and 15° metal seal (XT-M, TurboTorque-M) of the box before making up the connection for the trip in the hole. Trapped drilling fluid can promote corrosion of the secondary shoulders.

• Racking the pipe will wipe thread compound off the secondary shoulder and pin nose. If pins are doped coming out of the hole, reapply compound to the secondary shoulder before the connections are made-up.

NOTE: For XT-M and TurboTorque-M connections, localized corrosion or pitting may occur on the 15° metal seal if racked back without thread compound applied to it. This is more common with comple-tion fluids than common drilling fluids. Apply a liberal and even coat of quality thread compound to the 15° seal when racking back XT-M and TurboTorque-M connections.

15° Metal Seal

SecondaryShoulder

Threads

PrimaryShoulder


23

Tonging and Proper Gripping of the Box During Makeup• Tongs should be placed per chart below:

See Chart, column B.

Recommended Tonging Area

A.Connection

B.Minimum Grip Distance from

Makeup Shoulder(in)

C.Minimum Tong

Pin(in)

Box(in)

API 75% OD, 4 min box depth + 1

GPDS™ 75% OD, 4 min box depth + 1

XT-M™, GT-M™, XT® long

counterbore2 6 8

CT-M™57 1 6 7

CT-M™43 1 6 7

TT® and TT-M™ mid sizes 2 6 8

XT® short counterbore 1.5 6 7.5

TT® and TT-M™ small sizes 1 6 7

TT® and TT-M™ large sizes 1.5 6 7.5

• Back-up tongs should always be used.


24

P

P

Tong Height

• Bucking up tool joints with tongs can put high bending loads in the pipe.

• Review the IADC Drilling Manual Latest Edition or Tong Height Figure in API RP7G Latest Editon about height of tool joint above slips to prevent bending pipe during tonging.

H max


25

Box

Pin

Contact of sharp edge of pin thread on box flank

Alignment when Making up Connections

• Galling and other damage can occur during stabbing and spinning connections up.

• A stand of pipe can weigh between 1,500 lbs and 2,300 lbs. At initial contact, the weight could be supported by the sharp edge of one thread against the flank of the mating thread (see figure below). This can cause high contact stresses and may wipe the thread compound off.

• Slight misalignment of the pin and box can cause further increases in the stresses when spinning up.

• The “whipping” action of spinning pipe can cause high loads on threads.

NOTE: Alignment of the pin to the box when stabbing and spinning up is more critical for XT® and XT-M™ connections. A stabbing guide is required when running XT and XT-M. Alignment for all connec-tions should be verified before spinning up.

Tripping• Alternate breaks when tripping so that each joint will be broken-out

every third trip.

• Monitor break-out torque.

• The break-out torque should be less than the make-up torque. High break-out torque is an indication of down-hole make-up or thread damage.

• Do not let the end of the pin strike the box make-up shoulder when stabbing the pin in the box. Stabbing guides are required for XT and XT-M connections, and recommended for all other Grant Prideco proprietary connections.


26

Standing Pipe Back

• Using normal drill pipe care and handling practices, no special care is required to protect the pin nose when standing the pipe back. The pin nose is not a seal. Minor damage to the pin nose from standing the pipe back does not affect the connection’s performance. Remove protruding metal with a soft grinding wheel or standard file.

• It is not necessary to use thread protectors when standing the pipe back.

• Do not use pressed steel thread protectors when standing pipe back. They could allow the weight of the stand to be supported by the primary make-up shoulder of the connection on the sharp edge of the thread protectors.

• Apply a liberal and even coat of quality thread compound to the 15° metal seal when racking back XT-M™ and TurboTorque-M™ connections.

Sharp edge of thread protector can damage shoulder.


27

Milled hardness flat

Punch marks

Apply punch marks in line with hardness flat to make them easier to find.

• Downhole make-up can be detected by high break-out torque. The break-out torque should be less than the make-up torque.

• If downhole make-up is suspected, punch mark the pin and box next to the make-up shoulders when tripping into the hole (after the con-nection is made up).

• If downhole make-up occurs, the position of the punch marks will change.

• Downhole make-up can cause

– Compressed box counterbores

– Compressed pin noses

Downhole Make-up


28

The following sections provide information and general guidelines regarding the field inspection of Grant Prideco double shoulder connections and are not intended to replace NOV Grant Prideco Field Inspection Procedures and Drawings.

Connection type-specific Field Inspection Procedures and connection type and size- specific Field Inspection Drawings are available direct from NOV Grant Prideco and can be downloaded from: www.nov.com/grantprideco.com

Make-up Shoulder and Bevel Diameter• The primary make-up shoulders provide the seal for the connection

(HT®, XT®, GPDS®, TurboTorque®). For XT-M™ and TurboTorque-M™, the primary seal is the 15° metal seal and the backup seal is the primary make-up shoulder.

• The primary make-up shoulders and 15° metal seal (XT-M, TurboTorque-M) should be inspected frequently using current NOV Grant Prideco Field Inspection Procedures for the applicable connection type.

• Proper operation and correct shoulder loads depend on the pin length and box depth of double shoulder connections being within specifications. The pin length and box depth are shown on the Field Inspection Drawing for the particular size and type connection.

• No more than 1/32” should be removed from either the primary or secondary make-up shoulder at any one refacing. No more than 1/16” cumulatively should be removed from either the primary or secondary make-up shoulder. The correct pin length and box depth must be maintained when resurfacing make-up shoulders.

• The NOV Grant Prideco benchmark and Xmark™ benchmark are references for checking how much material has been removed from make-up shoulders.

• The surface finish of the primary make-up shoulder should be 150 RMS or better.

• When NOV Grant Prideco double shoulder connections are refaced, the bevel does not need to be remachined.

• The pin nose is not a seal, it is a mechanical stop. The pin nose must be free of raised metal or other imperfections that could prevent proper make up or cause galling. Pin nose damage can be repaired with a hand file.

• Refacing is not allowed for metal seals and must be redressed by an NOV GRP licensed machine shop.


29

Box

1 2 3

Pin

NOV Grant Prideco Benchmark

Unlike the API "tangent bar", the NOV Grant Prideco benchmark step

provides a reference that is visible from any position around the

connection circumference.

1

1

1 2 3


30

Checking Pin Length

• The pin length can be checked with a dial indicator or depth micrometer. If the pin length is short by 1/32 inch or less, the pin can be repaired by resurfacing the primary shoulder.

• If the pin length is short by more than 1/32 inch, the pin must be recut.

• If the pin length is too long by 1/32 inch or less, the pin can be repaired by resurfacing the pin nose.

• If the pin length is too long by more than 1/32 inch, the pin must be recut.

If the pin nose does not contact the gauge when used as shown in the figure, the length should be inspected with measuring instruments that determine the actual distance between the shoulders.


31

If the primary shoulder does not contact the gauge when used as shown in the figure, the depth should be inspected with measuring instruments that determine the actual distance between the shoulders.

• The box depth can be checked with a dial indicator or depth microm-eter. If the box depth is short by 1/32 inch or less, the box can be repaired by resurfacing the secondary shoulder.

• If the box depth is short by more than 1/32 inch, the box must be recut.

• If the box depth is too long by 1/32 inch or less, the box can be repaired by resurfacing the primary shoulder.

• If the box depth is too long by more than 1/32 inch, the box must be recut.

Checking Box Depth


32

Box Seal

Pin Seal

0.188

0.060

0.060

Special Considerations When Inspecting XT®, TurboTorque®, XT-M™ and TurboTorque-M™ Connections

• For XT and XT-M, the stab flank to crest radius of the starting four to five threads of the pin and box connections round off during break-in and normal operation. Minor thread damage may occur within these starting threads. This is not detrimental to the connection and pro-truding metal should be removed with a soft grinding wheel or a file.

• The XT-M and TurboTorque-M connections contain a 15° metal seal near the pin and box secondary shoulders. This is the primary sealing surface for the connection.

– Round pit type defects up to 1/32” in diameter and not exceeding 1/32” in depth are permissible.

– Multiple pits of this type are acceptable provided there is at least a 1” separation between pits, along the circumference of the seal.

– Circumferential lines or marks are acceptable provided they cannot be detected by rubbing a fingernail across the surface.

– Areas highlighted in the figure below are the non-contacting areas of the seal. Damage or pitting is permitted in these areas of the seal provided the balance of the contact surface is without damage exceeding the requirements above.

– XT-M and TT-M connections may not be refaced. Damages exceeding requirements for the threads, seal and/or shoulder faces require the connection to be redressed by Grant Prideco licensed machine shops.


33

Beve

lDi

aNo

seDi

aPi

n Cy

linde

rDi

a

Thre

ad Fo

rm

Pin

Leng

th

Field Inspection Drawing – Pin


34

TurboTorque® Field Inspection Dimensions – Pin

Connection Thread1Radius

Pin Length (in)

Bevel Dia (in)

Pin Cylinder Dia (in)

Nose Dia2(in)

TurboTorque 380 TT 0.75 / 3.5 4.679-4.688 4.524-4.681 3.869-3.915 3.388-3.435

TurboTorque 390 TT 0.75 / 3.5 4.554-4.563 4.675-4.832 3.969-4.015 3.496-3.543

TurboTorque 420 TT 0.75 / 3.5 4.679-4.688 5.012-5.169 4.269-4.315 3.788-3.835

TurboTorque 435 TT 0.75 / 3.5 4.616-4.625 5.151-5.308 4.419-4.465 3.942-3.989

TurboTorque 485 TT 0.75 / 3.5 5.554-5.563 5.701-5.858 4.919-4.965 4.383-4.430

TurboTorque 500 TT 1.00 / 3.0 5.304-5.313 5.960-6.117 5.076-5.122 4.452-4.499

TurboTorque 525 TT 1.00 / 3.0 5.741-5.750 6.160-6.317 5.326-5.372 4.665-4.712

TurboTorque 550 TT 1.00 / 3.0 4.741-4.750 6.353-6.510 5.576-5.622 4.999-5.046

TurboTorque 585 TT 1.00 / 3.0 5.054-5.063 6.766-6.923 5.926-5.972 5.323-5.370

TurboTorque 690 TT 1.25 / 3.0 5.429-5.438 7.936-8.093 6.962-7.008 6.184-6.231

Note: 1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco. 2. This reference dimension is not used to determine acceptance or rejection, but to test for pin nose swell

and the need to verify connection length.


35

TurboTorque-M™ Field Inspection Dimensions – Pin

Connection Thread1 Radius

Pin Length (in)

Bevel Dia (in)


Nose Dia2(in)2

TurboTorque-M 380 TT 0.75 / 3.5 5.12 - 5.125 4.524-4.681 3.869-3.915 3.203

TurboTorque-M 390 TT 0.75 / 3.5 4.995 - 5.000 4.675-4.832 3.969-4.015 3.311

TurboTorque-M 420 TT 0.75 / 3.5 5.120 - 5.125 5.012-5.169 4.269-4.315 3.603

TurboTorque-M 435 TT 0.75 / 3.5 5.058 - 5.063 5.151-5.308 4.419-4.465 3.757

TurboTorque-M 485 TT 0.75 / 3.5 5.995 - 6.000 5.701-5.858 4.919-4.965 4.198

TurboTorque-M 500 TT 1.00 / 3.0 5.745 - 5.750 5.960-6.117 5.076-5.122 4.267

TurboTorque-M 525 TT 1.00 / 3.0 6.183 - 6.188 6.160-6.317 5.326-5.372 4.480

TurboTorque-M 550 TT 1.00 / 3.0 5.183 - 5.188 6.353-6.510 5.576-5.622 4.814

TurboTorque-M 585 TT 1.125 / 3.0 5.495 - 5.500 6.766-6.923 5.926-5.972 5.138

Note: 1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco. 2. This reference dimension is not used to determine acceptance or rejection, but to test for pin nose swell



36

XT® Field Inspection Dimensions – Pin

Connection Thread1Radius

Pin Length (in)

Bevel Dia (in)


Nose Dia2(in)

XT24 V 042R 3.210-3.219 2.984-3.141 2.490-2.536 2.067-2.114

XT26 V 042R 3.116-3.125 3.203-3.360 2.728-2.774 2.309-2.356

XT29 V 042R 3.647-3.656 3.578-3.735 3.029-3.075 2.594-2.605

XT30 V 042R 3.366-3.375 3.703-3.860 3.174-3.220 2.740-2.787

XT31 V 042R 3.991-4.000 3.859-4.016 3.235-3.281 2.777-2.756

XT34 V 042R 4.147-4.156 4.109-4.266 3.535-3.581 3.063-3.110

XT38 V 042R 4.616-4.625 4.547-4.704 3.844-3.885 3.332-3.378

XT39 V 042R 4.491-4.500 4.770-4.927 4.026-4.072 3.531-3.578

XT40 V 042R 4.491-4.500 5.000-5.157 4.234-4.280 3.735-3.782

XT43 V 042R 3.647-3.656 5.047-5.204 4.385-4.431 3.927-3.974

XT46 V 042R 7.491-7.500 5.918-6.075 4.920-4.966 4.321-4.368

XT50 V 042R 7.291-7.300 6.302-6.459 5.306-5.352 4.743-4.790

XT54 V 042R 6.991-7.000 6.453-6.610 5.564-5.610 5.020-5.067

XT55 V 042R 7.241-7.250 6.857-7.014 5.680-5.726 5.101-5.148

XT57 V 042R 7.241-7.250 6.705-6.862 5.806-5.852 5.262-5.309

XT61 V 042R 6.241-6.250 6.961-7.118 6.213-6.259 5.530-5.577

XT65 V 042R 8.241-8.250 7.703-7.860 6.681-6.727 6.074-6.121

XT69 V 042R 7.804-7.813 7.797-7.954 7.056-7.102 6.476-6.523

Note: 1. Thread form for XT® is proprietary to NOV Grant Prideco. 2. This reference dimension is not used to determine acceptance or rejection, but to test for pin nose swell



37

XT-M™ Field Inspection Dimensions – Pin

Connection Thread Radius

Pin Length (in)

Bevel Dia (in)


Nose Dia2(in)

XT-M24 V 042R 5.054-5.063 2.984-3.141 2.490-2.536 1.882

XT-M26 V 042R 4.991-5.000 3.203-3.360 2.728-2.774 2.124

XT-M29 V 042R 5.491-5.500 3.578-3.735 3.029-3.075 2.393

XT-M31 V 042R 5.866-5.875 3.859-4.016 3.235-3.281 2.576

XT-M34 V 042R 5.991-6.000 4.078-4.235 3.535-3.581 2.873

XT-M38 V 042R 6.491-6.500 4.547-4.704 3.844-3.890 3.146

XT-M39 V 042R 6.241-6.250 4.770-4.927 4.026-4.072 3.360

XT-M40 V 042R 6.491-6.500 5.000-5.157 4.234-4.280 3.550

XT-M43 V 042R 5.616-5.625 5.047-5.204 4.385-4.431 3.742

XT-M46 V 042R 7.491-7.500 5.918-6.075 4.920-4.966 4.136

XT-M50 V 042R 7.291-7.300 6.302-6.459 5.306-5.352 4.558

XT-M57 V 042R 7.241-7.250 6.705-6.862 5.806-5.852 5.076

XT-M61 V 042R 6.241-6.250 6.961-7.118 6.213-6.259 5.345

XT-M65 V 042R 8.241-8.250 7.703-7.860 6.681-6.727 5.889

XT-M67 V 042R 7.991-8.000 7.734-7.891 6.824-6.870 6.048

XT-M69 V 042R 7.804-7.813 7.797-7.954 7.056-7.102 6.291

Note: 1. Thread form for XT-M™ is proprietary to NOV Grant Prideco. 2. This reference dimension is not used to determine acceptance or rejection, but to test for pin nose swell



38

GPDS® Field Inspection Dimensions – Pin


Pin Length (in)

Bevel Dia (in)


Nose Dia1(in)

GPDS26 V 038R 3.372-3.383 3.250-3.407 2.719-2.765 1.985-2.031

GPDS31 V 038R 3.884-3.895 3.937-4.094 3.235-3.281 2.423-2.469

GPDS38 V 038R 4.396-4.407 4.562-4.719 3.860-3.906 2.954-3.000

GPDS40 V 038R 4.907-4.918 5.000-5.157 4.125-4.171 3.141-3.187

GPDS46 V 038R 4.907-4.918 5.703-5.860 4.678-4.724 3.688-3.734

GPDS50 V 038R 4.907-4.918 6.047-6.204 5.104-5.150 4.110-4.156

GPDS55 V 050 5.420-5.431 6.703-6.860 5.688-5.734 4.548-4.594

GPDS65 V 050 5.420-5.431 7.687-7.844 6.616-6.662 5.469-5.515

Note: 1. This reference dimension is not used to determine acceptance or rejection, but to test for pin nose swell



39

HT® Field Inspection Dimensions – Pin


Pin Length (in)

Bevel Dia (in)


Nose Dia1(in)

2-3/8 HTSLH90 90°V 084 4.429-4.438 2.984-3.141 2.607-2.653 2.216-2.263

2-7/8 HTPAC V 076S 4.821-4.830 3.047-3.204 2.406-2.452 1.967-2.014

HT26 V 038R 5.156-5.165 3.296-3.453 2.719-2.765 2.109-2.156

HT31 V 038R 5.334-5.343 3.937-4.094 3.360-3.406 2.574-2.621

HT38 V 038R 5.496-5.505 4.637-4.794 3.880-3.926 3.172-3.219

HT40 V 038R 6.267-6.276 4.859-5.016 4.125-4.171 3.306-3.353

HT46 V 038R 6.282-6.291 5.829-5.986 4.678-4.724 3.859-3.906

HT50 V 038R 6.150-6.159 6.124-6.281 5.094-5.140 4.297-4.344

HT55 V 050 7.338-7.347 6.857-7.014 5.720-5.735 4.667-4.713

HT65 V 050 7.491-7.500 7.547-7.704 6.616-6.662 5.566-5.613




40

Beve

lDi

aCo

unte

rbor

eDi

a

Coun

terb

ore

Wal

l

Box D

epth

Field Inspection Drawing – Box

Thre

ad Fo

rm


41

TurboTorque® Field Inspection Dimensions – Box

Connection Thread Radius1

Box Depth (in)

Bevel Dia (in)

Counterbore Dia (in)

Min C Bore Wall (in)

TurboTorque 380 TT 0.75/3.5 4.686-4.691 4.524-4.681 3.946-4.008 0.25

TurboTorque 390 TT 0.75/3.5 4.561-4.566 4.675-4.832 4.046-4.108 0.25

TurboTorque 420 TT 0.75/3.5 4.686-4.691 5.012-5.169 4.346-4.408 0.25

TurboTorque 435 TT 0.75/3.5 4.623-4.628 5.151-5.308 4.496-4.558 0.313

TurboTorque 485 TT 0.75/3.5 5.561-5.566 5.701-5.585 4.996-5.058 0.313

TurboTorque 500 TT 1.00/3.0 5.311-5.316 5.960-6.117 5.158-5.220 0.313

TurboTorque 525 TT 1.00/3.0 5.748-5.753 6.160-6.317 5.408-5.470 0.313

TurboTorque 550 TT 1.00/3.0 4.748-4.753 6.353-6.510 5.658-5.720 0.313

TurboTorque 585 TT 1.00/3.0 5.061-5.066 6.766-6.923 6.008-6.070 0.313

TurboTorque 690 TT 1.25/3.0 5.438-5.443 7.936-8.093 7.133-7.195 0.313

Note: 1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco.


42

TurboTorque-M™ Field Inspection Dimensions – Box

Connection Thread Radius1

Box Depth (in)

Bevel Dia (in)



TurboTorque-M 380 5.123-5.128 4.524-4.681 3.946-4.008 0.25

TurboTorque-M 390 4.998-5.003 4.675-4.832 4.046-4.108 0.25

TurboTorque-M 420 5.123-5.128 5.012-5.169 4.346-4.408 0.25

TurboTorque-M 435 5.061-5.066 5.151-5.308 4.496-4.558 0.313

TurboTorque-M 485 5.998-6.003 5.701-5.858 4.996-5.058 0.313

TurboTorque-M 500 5.750-5.755 5.960-6.117 5.158-5.220 0.313

TurboTorque-M 525 6.188-6.193 6.160-6.317 5.408-5.470 0.313

TurboTorque-M 550 5.188-5.193 6.353-6.510 5.658-5.720 0.313

TurboTorque-M 585 5.500-5.505 6.766-6.923 6.008-6.070 0.313

Note: 1. Thread form for TurboTorque® is proprietary to NOV Grant Prideco.


43

XT® Field Inspection Dimensions – Box


Box Depth (in)

Bevel Dia (in)



XT24 V 042R 3.217-3.222 2.984-3.141 2.593-2.655 0.188

XT26 V 042R 3.123-3.128 3.203-3.360 2.831-2.893 0.188

XT29 V 042R 3.654-3.659 3.578-3.735 3.132-3.194 0.188

XT30 V 042R 3.373-3.378 3.703-3.860 3.267-3.329 0.188

XT31 V 042R 3.998-4.003 3.859-4.016 3.342-3.404 0.188

XT34 V 042R 4.154-4.159 4.109-4.266 3.638-3.700 0.188

XT38 V 042R 4.623-4.628 4.547-4.704 3.947-4.009 0.250

XT39 V 042R 4.498-4.503 4.770-4.927 4.121-4.183 0.250

XT40 V 042R 4.498-4.503 5.000-5.157 4.324-4.386 0.250

XT43 V 042R 3.654-3.659 5.047-5.204 4.488-4.550 0.313

XT46 V 042R 7.505-7.510 5.918-6.075 5.071-5.133 0.313

XT50 V 042R 7.305-7.310 6.302-6.459 5.409-5.471 0.313

XT54 V 042R 7.005-7.010 6.453-6.610 5.667-5.729 0.313

XT55 V 042R 7.255-7.260 6.857-7.014 5.783-5.845 0.313

XT57 V 042R 7.255-7.260 6.705-6.862 5.909-5.971 0.313

XT61 V 042R 6.255-6.260 6.961-7.118 6.316-6.378 0.313

XT65 V 042R 8.255-8.260 7.703-7.860 6.784-6.846 0.313

XT69 V 042R 7.818-7.823 7.797-7.954 7.159-7.221 0.313

Note: 1. Thread form for XT® is proprietary to NOV Grant Prideco.


44

XT-M™ Field Inspection Dimensions – Box


Box Depth (in)

Bevel Dia (in)



XT-M24 V 042R 5.068-5.073 2.984-3.141 2.593-2.655 0.188

XT-M26 V 042R 5.005-5.010 3.203-3.360 2.831-2.893 0.188

XT-M29 V 042R 5.505-5.510 3.578-3.735 3.132-3.194 0.188

XT-M31 V 042R 5.880-5.885 3.859-4.016 3.342-3.404 0.188

XT-M34 V 042R 6.005-6.010 4.078-4.235 3.638-3.700 0.250

XT-M38 V 042R 6.505-6.510 4.547-4.704 3.947-4.009 0.250

XT-M39 V 042R 6.255-6.260 4.770-4.927 4.129-4.191 0.250

XT-M40 V 042R 6.505-6.510 5.000-5.157 4.358-4.386 0.250

XT-M43 V 042R 5.630-5.635 5.047-5.204 4.488-4.550 0.313

XT-M46 V 042R 7.505-7.510 5.918-6.075 5.071-5.133 0.313

XT-M50 V 042R 7.305-7.310 6.302-6.459 5.409-5.471 0.313

XT-M57 V 042R 7.255-7.260 6.705-6.862 5.909-5.971 0.313

XT-M61 V 042R 6.255-6.260 6.961-7.118 6.316-6.378 0.313

XT-M65 V 042R 8.255-8.260 7.703-7.860 6.784-6.846 0.313

XT-M67 V 042R 8.005-8.010 7.734-7.891 6.927-6.989 0.313

XT-M69 V 042R 7.818-7.823 7.797-7.954 7.159-7.221 0.313

Note: 1. Thread form for XT-M™ is proprietary to NOV Grant Prideco.


45

GPDS® Field Inspection Dimensions – Box


Box Depth (in)

Bevel Dia (in)



GPDS26 V 038R 3.378-3.389 3.250-3.407 2.899-2.961 0.188

GPDS31 V 038R 3.890-3.901 3.937-4.094 3.414-3.476 0.188

GPDS38 V 038R 4.402-4.415 4.562-4.719 4.039-4.101 0.250

GPDS40 V 038R 4.915-4.927 5.000-5.157 4.305-4.367 0.250

GPDS46 V 038R 4.915-4.927 5.703-5.860 4.867-4.929 0.313

GPDS50 V 038R 4.915-4.927 6.047-6.204 5.274-5.336 0.313

GPDS55 V 050 5.427-5.439 6.703-6.860 5.867-5.929 0.313

GPDS65 V 050 5.427-5.439 7.687-7.844 6.805-6.867 0.313




46

HT® Field Inspection Dimensions – Box


Box Depth (in)

Bevel Dia (in)



2-3/8 HTSLH90 90°V 084 4.443-4.448 2.984-3.141 2.727-2.789 0.094

2-7/8 HTPAC V 076S 4.835-4.840 3.047-3.204 2.539-2.601 0.188

HT26 V 038R 5.168-5.173 3.296-3.453 2.907-2.969 0.188

HT31 V 038R 5.351-5.356 3.937-4.094 3.422-3.484 0.188

HT38 V 038R 5.510-5.515 4.637-4.794 4.047-4.109 0.313

HT40 V 038R 6.281-6.286 4.859-5.016 4.313-4.375 0.313

HT46 V 038R 6.296-6.301 5.829-5.986 4.875-4.937 0.313

HT50 V 038R 6.164-6.169 6.124-6.281 5.282-5.344 0.313

HT55 V 050 7.352-7.357 6.857-7.014 5.875-5.937 0.313

HT65 V 050 7.504-7.509 7.547-7.704 6.813-6.875 0.313




HEA

VY W

EIGH

TD

RILL PIPE

Heavy Weight Drill Pipe

Standard Heavy Weight Drill Pipe

Heavy Weight drill pipe (HWDP) was developed to provide a gradual

transition from heavy drill collars to relatively lightweight drill pipe. By

providing a gradual change in weight and rigidity, HWDP reduces

connection fatigue problems and increases drill stem service life. And,

because it bends more easily than drill collars, it simplifies directional

control in high-angle and horizontal drilling. HWDP has less wall contact

than drill collars, reducing differential sticking tendencies. Spiraled HWDP

configurations further decrease differential sticking tendency while

helping to remove cuttings out of the annulus. NOV Grant Prideco offers

three types of HWDP configurations to meet the challenge of severe

drilling conditions.

· Standard HWDP – Developed to provide a gradual transition from the

heavy drill collar to the relatively lightweight drill pipe.

47

24”

DTool Joint

OD

BUpset Diameter

ANominal Size

CWear Section

Upset Diameter

BElevator Upset

Diameter

18°

18°

26”

24”

31’ Nominal Length



• Tri-Spiral™ HWDP – Developed for high-angle applications such as

extended reach and horizontal drilling.

– Equally spaced, three spiral upset design helps improve cuttings

removal, reduce differential sticking tendencies and torque and

drag.

Tri-Spiral Heavy Weight Drill Pipe

48

p

DPin Tool

Joint

CSpiral Upset

C Center Spiral Upset

CSpiral Upset

DBox Tool

Joint

BElevator

Upset Diameter

BUpset Diameter

ANominal Size


24”

26”

26”

26”

24”


49

Heavy Weight Drill Pipe (HWDP)

· Spiral-Wate® HWDP – Designed to handle maximum stress to save time and reduce drilling costs, especially in tough drilling environments.

- Unique patented spiral design reduces differential sticking problems, minimizes wear and improves circulation. Features more weight per joint and better hole cleaning characteristics than standard HWDP.

Spiral-Wate® Heavy Weight Drill Pipe


24”

DBox Tool

Joint

BElevator Upset

Diameter

CSpiral Upset

ANominal

Size

DPin Tool

Joint

42”

21'4”

9”

24”

TAB 3 RSHandbook_Heavyweight.indd 49TAB 3 RSHandbook_Heavyweight.indd 49 11/18/2010 5:37:31 PM11/18/2010 5:37:31 PM

50

Dimensional Data - Range IISt

anda

rd H

eavy

Wei

ght D

rill P

ipe

Tube

Tool

Join

tAs

sem

bly

Nom

inal

Dim

ensio

nsM

echa

nica

l Pr

oper

ties

Nom

inal

Dim

ensio

nsM

echa

nica

l Pr

oper

ties

Adju

sted

W

eigh

t

Nom

inal

Size (A

)

ID (in)

Wal

lTh

ickne

ss

(in)

Area

(sq in

)

Sect

ion

Mod

ulus

(cu in

)

Spira

lUp

set D

ia(C

)(in

)

End

Upse

t Dia

(B)

(in)

Tens

ileYi

eld

(lb)

Tors

iona

lYi

eld

(ft-lb

)

Conn

ectio

nSi

ze an

d Typ

e

OD (D)

(in)

ID (in)

Tens

ileYi

eld

(lb)

Tors

iona

lYi

eld

(ft-lb

)

Per

Foot

(lb)

Per

31 ft

Join

t (lb

)

Mak

e-up

Torq

ue

(ft-lb

)

3 1/

22

1/16

0.71

96.

282

3.70

24

3 7/

834

5,50

019

,600

NC

38 (3

1/2

IF)

4 3/

4 2

1/1

686

7,10

019

,200

25.6

579

511

,500

3 1/

22

1/4

0.62

55.

645

3.49

04

3 7/

831

0,50

018

,500

NC

38 (3

1/2

IF)

HT®

38

XT®

39

4 3/

44

7/8

4 7/

82

1/4

790,

900

790,

900

871,

700

19,2

0034

,200

40,7

00

23.4

823

.96

23.9

6

728

743

743

11,5

0020

,500

24,4

00

42

9/16

0.71

97.

411

5.22

54

1/2

4 3/

1640

7,60

027

,600

NC

40 (4

FH

)XT

® 39

5 1/

44

7/8

2 9/

1683

8,30

072

9,70

027

,800

37,0

0029

.92

28.4

092

888

014

,600

22,2

00

4 1/

22

3/4

0.87

59.

965

7.69

85

4 11

/16

548,

100

40,7

00N

C 46

(4 IF

)6

1/4

2 3/

41,

183,

900

44,9

0041

.45

1,28

523

,200

53

1.00

012

.566

10.6

815

1/2

5 1/

869

1,20

056

,500

NC

50 (4

1/2

IF)

HT®

50

6 5/

83

1416

,200

58,0

0088

,000

50.3

81,

562

30,0

0053

,300

5 1/

23

1/4

1.12

515

.463

14.3

426

5 11

/16

850,

400

75,9

005

1/2

FHH

T®55

7 1/

43

1/4

1,77

8,30

078

,500

115,

100

61.6

31,

911

41,2

0069

,000

*

5 7/

84

0.93

814

.542

15.6

306

3/8

679

9,80

082

,700

XT®5

77

41,

403,

100

106,

200

57.4

21,

780

63,7

00*

6 5/

84

1/2

1.06

318

.574

22.4

767

1/8

6 15

/16

1,02

1,60

011

8,90

06

5/8

FH8

4 1/

21,

896,

100

88,0

0071

.43

2,21

450

,500

Note

s: To

rque

figu

res w

ith *

indi

cate

redu

ced m

ake u

p for

typi

cally

cham

fere

d con

nect

ion.


51

Dimensional Data - Range IITR

I-SPI

RAL™

Hea

vy W

eigh

t Dril

l Pip

e

Tube

Tool

Join

tAs

sem

bly

Nom

inal

Dim

ensio

nsM

echa

nica

l Pr

oper

ties

Nom

inal

Dim

ensio

nsM

echa

nica

l Pr

oper

ties

Adju

sted

W

eigh

t

Nom

inal

Size (A)

ID (in)

Wal

lTh

ickne

ss

(in)

Area

(sq in

)

Sect

ion

Mod

ulus

(cu in

)

Spira

lUp

set D

ia(C

)(in

)

End

Upse

t Dia

(B)

(in)

Tens

ileYi

eld

(lb)

Tors

iona

lYi

eld

(ft-lb

)

Conn

ectio

nSi

ze an

dTy

pe

OD (D)

(in)

ID (in)

Tens

ileYi

eld

(lb)

Tors

iona

lYi

eld

(ft-lb

)

Per

foot

(in)

Per

31 ft

Join

t (lb

)

Mak

e-up

Torq

ue

(ft-lb

)

3 1/

22

1/16

0.71

96.

282

3.70

24

3 7/

834

5,50

019

,600

NC

38 (3

1/2

IF)

4 3/

4 2

1/1

686

7,10

019

,200

27.0

583

911

,500

3 1/

22

1/4

0.62

55.

645

3.49

04

3 7/

831

0,50

018

,500

NC

38 (3

1/2

IF)

HT®

38

XT®

39

4 3/

44

7/8

4 7/

82

1/4

790,

900

790,

900

871,

700

19,2

0034

,200

40,7

00

24.8

825

.36

25.3

6

771

786

786

11,5

0020

,500

24,4

00

42

9/16

0.71

97.

411

5.22

54

1/2

4 3/

1640

7,60

027

,600

NC

40 (4

FH

)XT

® 39

5 1/

44

7/8

2 9/

1683

8,30

072

9,70

027

,800

37,0

0031

.51

29.9

997

793

014

,600

22,2

00

4 1/

22

3/4

0.87

59.

965

7.69

85

4 11

/16

548,

100

40,7

00N

C 46

(4 IF

)6

1/4

2 3/

41,

183,

900

44,9

0043

.31

1,34

323

,200

53

1.00

012

.566

10.6

815

1/2

5 1/

869

1,20

056

,500

NC

50 (4

1/2

IF)

HT®

50

6 5/

83

1416

,200

58,0

0088

,000

52.3

41,

623

30,0

0053

,300

5 1/

23

1/4

1.12

515

.463

14.3

426

5 11

/16

850,

400

75,9

005

1/2

FHH

T® 5

57

1/4

3 1/

41,

778,

300

78,5

0011

5,10

063

.78

1,97

741

,200

69,0

00*

5 7/

84

0.93

814

.542

15.6

306

3/8

679

9,80

082

,700

XT®5

77

41,

403,

100

106,

200

57.4

21,

780

63,7

00*

6 5/

84

1/2

1.06

318

.574

22.4

767

1/8

6 15

/16

1,02

1,60

011

8,85

06

5/8

FH8

4 1/

21,

896,

100

88,0

0074

.67

2,31

550

,500

Note

s: To

rque

figu

res w

ith *

indi

cate

redu

ced m

ake u

p for

typi

cally

cham

fere

d con

nect

ion.


52

Dimensional Data - Range IISP

IRAL

-WAT

E® D

rill P

ipe m

echa

nica

l pro

pert

ies

Tube

Tool

Join

tAs

sem

bly

Nom

inal

Dim

ensio

nsM

echa

nica

l Pr

oper

ties

Nom

inal

Dim

ensio

nsM

echa

nica

l Pr

oper

ties

Adju

sted

W

eigh

t

Nom

inal

Size (A)

ID (in)

Wal

lTh

ickne

ss

(in)

Area

(sq in

)

Sect

ion

Mod

ulus

(cu in

)

Spira

lUp

set D

ia(C

)(in

)

End

Upse

t Dia

(B)

(in)

Tens

ileYi

eld

(lb)

Tors

iona

lYi

eld

(ft-lb

)

Conn

ectio

nSi

ze an

dTy

pe

OD (D)

(in)

ID (in)

Tens

ileYi

eld

(lb)

Tors

iona

lYi

eld

(ft-lb

)

Per

foot (lb

)

Per

31 ft

Join

t (l

b)

Mak

e-up

Torq

ue

(ft-lb

)

3 3/

161

20.

594

4.84

02.

687

3 5/

16N

/A53

2,40

028

,400

SLH

903

7/8

240

7,00

012

,000

19.4

860

46,

300

3 1/

22

1/4

0.62

55.

645

3.49

04

3 5/

831

0,50

018

,500

NC

38 (3

1/2

IF)

HT®

38

HT®

39

4 7/

82

1/4

790,

000

790,

900

871,

400

22,9

0034

,200

40,7

0030

.39

942

13,1

0020

,500

24,4

00

42

9/16

0.71

97.

411

5.22

54

1/2

4 1/

840

7,60

027

,600

NC

40 (4

FH

)XT

® 39

5 2

9/16

838,

300

729,

700

20,9

0040

,800

28.9

089

612

,600

24,5

002

4 1/

22

3/4

0.87

59.

965

7.69

85

4 5/

854

8,10

040

,700

NC

46 (4

IF)

6 1/

42

3/4

1,18

3,90

044

,900

49.5

31,

535

23,2

00

53

1.00

012

.566

10.6

815

1/2

5 1/

869

1,20

056

,500

NC

50 (4

1/2

IF)

HT®

50

6 5/

83

1,41

6,20

057

,800

88,8

0059

.16

1,83

430

,000

53,3

0002

5 1/

23

1/4

1.12

515

.463

14.3

426

5 5/

885

0,40

075

,900

5 1/

2 FH

HT®

55

73

1/4

1,77

8,30

053

,000

99,0

0069

.09

2,14

129

,200

46,3

002

5 7/

84

0.93

814

.542

16.6

306

3/8

679

9,80

082

,700

XT®

577

4 1,

403,

100

106,

200

65.3

82,

027

63,7

002

6 5/

84

1/2

1.06

318

.574

22.4

767

1/8

6 3/

41,

021,

600

118,

900

6 5/

8 FH

84

1/2

1,89

6,10

088

,000

82.1

22,

546

50,5

00

Note

s: 1.

3-3/

16 in

ch Sp

iral-W

ate,

pre

viou

sly re

ferr

ed to

as 2-

7/8 i

nch,

is o

nly m

anuf

actu

red a

s an

inte

gral

(non

-wel

ded)

des

ign.

2.

Red

uced

mak

eup f

or ty

pica

lly ch

amfe

red c

onne

ctio

n.


DRILL

COLLA

RS

Drill CollarsCare And Maintenance

Initial Make Up

Even though quality connections are heavily coated with phosphate, thread

damage is not always prevented. A generous and thorough application of

high-quality thread dope (40 to 60 percent metallic zinc minimum) will

help prevent galling.

New connections should be “walked in” with chain tongs. Always use the

recommended make-up torque for the thread design. Exercise care to

maintain calibrated torque measuring and indicating gauges for future use.

After initial make-up, break-out the connection, visually inspect, redope

and make-up two more times before running in the hole.

Note: Monitor break-out torque – it should be less than or no greater than make-up torque. If it is greater, the connection should be cleaned, inspected and repaired before it is made up again.

Maintenance

Use thread protectors on both connections when handling drill collars.

Alternate different joints on each trip. Clean and inspect the individual

connections.

Qualified personnel should periodically conduct a magnetic particle/black

light inspection. Collars that are left idle or put in storage should be

cleaned, inspected, repaired and rust-proofed as necessary before install-

ing thread protectors.

Hardbanding Repair and Re-Application

Extreme caution should be used when welding drill collar material in the

field. This material is high alloy steel; carefully heat-treated to provide

optimum performance. When repair welding or hardbanding, use proper

preheat, interpass and post-heat temperatures to prevent cracking and

metallurgical degradation of the collar.

Your NOV Grant Prideco licensed repair facility can provide welding repair

service to factory specifications to ensure weld area integrity. Contact your

representative today, or visit www.GrantPrideco.com for more information.

53


Care and Maintenance

Bending Strength Ratios

Sizes less than six inches should have a Bending Strength Ratio (BSR) of

2.25:1 to 2.75:1. For conditions that require high RPM and small collars

compared to the hole size, use 2.25:1 to 3.00:1. If the RPM is kept low

and the collars are closer to the hole size, use 2.25:1 to 3.20:1. In corrosive

environments, use 2.50:1 to 3.00:1.

The current industry BSR calculation for single-shoulder rotary-shouldered

connections are not applicable for double-shouldered connections (HT®,

XT®, GPDS®) as appropriate target ranges are yet to be defined due to limit-

ed industry experience and testing of available types/sizes.

Slip and Elevator Grooves

54

3”

A

B

C

3”3”

16”

18”

20”

Slip Grooved Elevator and Slip Grooved(zip grooved)

RCold Work

Shoulder Area

2” Radius

1” Radius

2” Radius

3”

18”

20”


55

Materials Mechanical Properties

Slip and Elevator Recess Dimensions

Drill Collar Diameter

Min. Yield Strength

Min. Tensile Strength

Min Hardness

(in) (psi) (psi) (BHN)

3-1/8 thru 6-7/8 110,000 140,000 285

7 thru 11 100,000 135,000 285

DrillCollar

Diameter

ElevatorRecess

Diameter

SlipRecess

Diameter

ElevatorRecessRadius

A B C R(in) (in) (in) (in)

4 1/8 3 11/16 3 3/4 1/8

4 3/4 4 1/4 4 3/8 1/8

5 4 1/2 4 5/8 1/8

5 1/4 4 3/4 4 7/8 1/8

6 5 3/8 5 1/2 1/8

6 1/4 5 5/8 5 3/4 1/8

6 1/2 5 7/8 6 1/8

6 3/4 6 6 1/4 3/16

7 6 1/4 6 1/2 3/16

7 1/4 6 1/2 6 3/4 3/16

7 3/4 7 7 1/4 3/16

8 7 1/4 7 1/2 3/16

8 1/4 7 1/2 7 3/4 3/16

8 1/2 7 3/4 8 3/16

9 8 1/8 8 1/2 1/4

9 1/2 8 5/8 9 1/4

9 3/4 8 7/8 9 1/4 1/4

10 9 1/8 9 1/2 1/4

11 10 1/8 10 1/2 1/4

Notes: On rework, minimum distance from face to box elevator should or end of hardbanding should be a length equivalent to depth of box or boreback plus two inches.

TAB 4 RSHandbook_Drill Collar.indd 55TAB 4 RSHandbook_Drill Collar.indd 55 11/18/2010 5:38:36 PM11/18/2010 5:38:36 PM

56

Recommended Minimum Make-up Torque for Rotary-Shouldered Drill Collar Connections

Connection Bore of Drill Collar (in)Size Type OD (in) 1 1 1/4

API NC 23

3*2,500 *2,500*3,300 *3,300

3 1/8*3,300 *3,300*4474 *4474

3 1/44,000 3,4005423 *4610

2 7/8 PAC3

3*3,800*5152

3 1/8*5,000

6644

3 1/45,2007050

2 3/8

API

2 3/8

API IF or

NC 26 or

Slim Hole

3 1/2*4,600*6237

3 3/45,5007457

2 7/8

3 1/2

2 7/8

Extra Hole or

Dbl. Streamline

or

Mod. Open

3 3/4*4,100*5559

3 7/8*5,400*7186

4 1/8*8,100*10847

2 7/8

API

3 1/2

API IF or

NC 31 or

Slim Hole

3 7/8*4,600*6237

4 1/8*7,400*9897

4 1/4*8,800*11931

4 1/210,30013558

API NC 35

4 1/2

4 3/4

5

3 1/2

4

3 1/2

Extra Hole or

Slim Hole or

Mod. Open

4 1/4

4 1/2

4 3/4

5

5 1/4

Refer to pages 68-69 for notes.


57

Bore of Drill Collar (in)1 1/2 1 3/4 2 2 1/4 2 1/2 2 13/16

*2,500*3,300

2,6003525

2,6003525

*3,800 2,900 *5152 3932

4,200 2,900 5694 3932

4,200 2,900 5694 3932

*4,600 3,700 *6237 5017

4,700 3,700 6372 5017

*4,100 *4,100 *5559 *5559

*5,400 *5,400*7186 7186

*8,100 7,400 *10847 10033

*4,600 *4,600 *4,600*6237 *6237 *6237

*7,400 *7,400 6,900*9897 *9897 9220

*8,900 8,200 6,900*11931 10982 9220

9,300 8,200 6,90012609 10982 9220

*9,000 *9,000 *9,000 7,400*12067 *12067 *12067 10033

12,300 *10,800 9,200 7,40016405 14643 12474 10033

12,300 10,800 9,200 7,40016405 14643 12474 10033

*5,200 *5,200 *5,200 *5,2006915 6915 6915 6915

*8,500 *8,500 *8,500 *8,300*11389 11389 11389 11118

*12,000 11,800 10,100 8,300*16134 15863 13558 11118

13,300 11,800 10,100 8,30017897 15863 13558 11118

13,400 11,800 10,100 8,30017897 15863 13558 11118

Foot-PoundsNewton-Meters



58

Connection Bore of Drill Collar (in)Size Type OD (in) 1 1 1/4 1 1/2

3 1/2

API

4 1/2

API IF or

NC 38 or

Slim Hole

4 3/4

5

5 1/4

5 1/2

3 1/2 H 904

4 3/4

5

5 1/4

5 1/2

4

API

4

4 1/2

Full Hole

NC 40 or

Mod Open or

Dbl. Streamline

5

5 1/4

5 1/2

5 3/4

6

4 H 904

5 1/4

5 1/2

5 3/4

6

6 1/4

4 1/2 API Regular

5 1/2

5 3/4

6

6 1/4




59

Bore of Drill Collar (in)1 3/4 2 2 1/4 2 1/2 2 13/16

*10,000 *10,000 *10,000 *10,000 *8,30013423 13423 13423 13423 *11253

*13,900 *13,900 12,900 11,000 8,300*18710 *18710 17354 14778 11253

16,200 14,600 12,900 11,000 8,30021693 19795 17354 14778 11253

16,200 14,600 12,900 11,000 8,30021693 19795 17354 14778 11253

*8,800 *8,800 *8,800 *8,800 *8,800*11796 *11796 *11796 *11796 *11796

*12,800 *12,800 *12,800 12,800 10,400*17219 *17219 *17219 17219 14101

*17,100 16,900 15,100 13,200 10,400*22913 22642 20337 17761 14101

18,500 16,900 15,100 13,200 10,40025083 22642 20337 17761 14101

*10,900 *10,900 *10,900 *10,900 *10,900*14643 *14643 *14643 *14643 *14643

*15,300 *15,300 *15,300 15,000 12,100*20473 *20473 *20473 20066 16405

*20,000 18,900 17,000 15,000 12,100*26710 25218 22913 20066 16405

20,500 18,900 17,000 15,000 12,10027659 25218 22913 20066 16405

20,500 18,900 17,000 15,000 12,10027659 25218 22913 20066 16405

*12,600 *12,600 *12,600 *12,600*16948 *16948 *16948 *16948

*17,400 *17,400 *17,400 *16,500*23456 *23456 *23456 22371

*22,300 21,500 19,500 16,500*30235 *29150 26303 22371

23,700 21,700 19,400 16,50031862 29150 26303 22371

23,700 21,700 19,500 16,50031862 29150 26303 22371

*15,600 *15,600 *15,600 *15,600*20880 *20880 *20880 *20880

*20,600 *20,600 19,600 16,600*27523 *27523 26303 21964

23,700 21,700 19,600 *16,60031726 29286 26303 21964

23,700 21,700 19,600 16,60031726 29286 26303 21964




60


Connection Bore of Drill Collar (in)Size Type OD in 1 1/2 1 3/4 2

API NC 44

5 3/4*20,900*27930

625,50033895

6 1/425,50033895

6 1/225,50033895

4 1/2 API Full Hole

5 1/2*13,000*17490

5 3/4*18,100*24269

6 *23,600*31591

6 1/4 27,30036607

6 1/2 27,30036607

4 1/2

API

4

4 1/2

5

4 1/2

Extra Hole

NC 46

API IF

Semi F

Dbl Streamline

Mod Open

5 3/4

6

6 1/4

6 1/2

6 3/4

4 1/2 H 904

5 3/4

6

6 1/4

6 1/2

6 3/4

5 H 904

6 1/4

6 1/2

6 3/4

7



61

Bore of Drill Collar (in)2 1/4 2 1/2 2 13/16 3 3 1/4

*20,900 *20,900 18,100*27930 *27930 24405

23,500 21,300 18,20031591 28743 24405

23,500 21,300 18,20031591 28743 24405

23,500 21,300 18,20031591 28743 24405

*13,000 *13,000 *13,000 *13,000*17490 *17490 *17490 *17490

*18,100 *18,100 *18,100 17,900*24269 *24269 *24269 23998

*23,600 23,000 19,900 17,900*31591 30913 26845 23998

*25,300 23,000 19,900 17,90033895 30913 26845 23998

25,300 23,000 19,900 17,90033895 30913 26845 23998

*17,700 *17,700 *17,700 *17,700*23862 *23862 *23862 *23862

*23,400 *23,400 22,400 20,30031455 31455 30099 27388

28,000 25,700 22,400 20,30037963 34573 30099 27388

28,000 25,700 22,400 20,30037963 34573 30099 27388

28,000 25,700 22,400 20,30037963 34573 30099 27388

*18,000 *18,000 *18,000 *18,000*23862 *23862 *23862 *23862

*23,700 *23,700 23,200 21,100*31726 *31726 31184 28472

28,700 26,400 23,200 21,10038641 35251 31184 28472

28,700 26,400 23,200 21,10038641 35251 31184 28472

28,700 26,400 23,200 21,10038641 35251 31184 28472

*25,400 *25,400 *25,400 *25,400*33895 *33895 *33895 *33895

*31,900 *31,900 29,400 27,200*42708 *42708 39997 36607

35,300 32,800 29,400 27,20047453 44742 39997 36607

35,300 32,800 29,400 27,20047453 44742 39997 36607




62



4 1/2

API

5

5

5 1/2

API IF or

NC 50 or

Extra Hole or

Mod Open or

Dbl. Streamline

or Semi IF

6 1/4*23,000 *23,000*30913 *30913

6 1/2*29,700 *29,700

39997 *39997

6 3/4*36,700 35,800*48809 48132

738,400 35,80051521 48132

7 1/438,400 35,80051521 48132

7 1/238,400 35,80051521 48132

5 1/2 H 904

6 3/4*34,500 *34,500*46098 46640

7*42,000 40,100*56266 54233

7 1/442,700 40,10057622 54233

7 1/242,700 40,10057622 54233

5 1/2 API Regular

6 3/4 *31,900 *31,900*42708 *42708

7*39,400 *39,400*52877 *52877

7 1/4 42,400 39,90056944 53555

7 1/2 42,400 39,90056944 53555

5 1/2 API Full Hole

7 *32,800*44064

7 1/4*41,000*54911

7 1/2 *49,700

66435

7 3/4 51,70069825

API NC 56

7 1/4*40,500

54233

7 1/2*49,100*65757

7 3/452,10069147

852,10069147



63

Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4*23,000 *23,000 *23,000*30913 *30913 *30913

*29,700 *29,700 26,700*39997 *39997 35929

32,300 30,000 26,70043657 40675 35929

32,300 30,000 26,70043386 40675 35929

32,300 30,000 26,70043386 40675 35929

32,300 30,000 26,70043386 40675 35929

*34,500 34,100*46098 46098

36,500 34,10049487 46098

36,500 34,10049487 46098

36,500 34,10049487 46098

*31,900 *31,900*42708 *42708

36,200 33,90048809 45420

36,200 33,90048809 45420

36,200 33,90048809 45420

32,800 32,800 *32,80044064 44064 *44064

*41,000 *41,000 *41,000*54911 *54233 *54911

47,800 45,200 41,50063723 61012 56266

47,800 45,200 41,50063723 61012 56266

*40,500 *40,500 *40,500*54233 *54233 *54233

48,200 45,700 42,10065079 61690 56944

48,200 45,700 42,10065079 61012 56944

48,200 45,700 42,10065079 61012 56944




64



6 5/8 API Regular

7 1/2*46,400*62368

7 3/4*55,600*74570

857,40077282

8 1/457,40077282

6 5/8 H 904

7 1/2*46,500*62368

7 3/4*55,700*74570

860,300*80671

8 1/460,30080671

API NC 61

8 *55,100*73214

8 1/4*65,400*86772

8 1/2 72,70097619

8 3/4 72,70097619

972,70097619

5 1/2 API IF

8 *56,600*75926

8 1/4*67,100*89484

8 1/2 74,600100331

8 3/4 74,600100331

974,600100331

9 1/4 74,000100331

6 5/8 API Full Hole

8 1/2

8 3/4

9

9 1/4

9 1/2



65

Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4*46,400 *46,400 *46,400*62368 *62368 *62368

53,300 50,700 46,90071858 67791 63723

53,300 50,700 46,90071858 67791 63723

53,300 50,700 46,90071858 67791 63723

*46,500 *46,500 *46,500*62368 *62368 *62368

55,700 53,600 49,900*74570 71858 67113

*56,300 53,600 49,900*75926 71858 67113

56,300 53,600 49,90075926 71858 67113

*55,100 *55,100 *55,100*73214 *73214 *73214

*65,400 *65,400 *61,600*86772 *86772 82705

68,400 65,600 61,60092196 88128 82705

68,400 65,600 61,60092196 88128 82705

68,400 65,600 61,60092196 88128 82705

*56,600 *56,600 *56,600 *56,600*75926 *75926 *75926 *75926

*67,100 *67,100 63,400 59,000*89484 *89484 85417 79993

70,300 67,400 63,400 59,00094907 90840 85417 79993

70,300 67,400 63,400 59,00094907 90840 85417 79993

70,300 67,400 63,400 59,00094907 90840 85417 79993

70,300 67,400 63,400 59,00094907 90840 85417 79993

*67,800 *67,800 *67,800 *67,800 67,200*90840 *90840 *90840 *90840 90162

*79,500 *79,500 76,700 72,100 67,200*105754 *105754 103042 97619 90162

84,000 80,100 76,700 72,100 67,200112533 108465 103042 97619 90162

84,000 80,100 76,700 72,100 67,200112533 108465 103042 97619 90162

84,000 80,100 76,700 72,100 67,200112533 108465 103042 97619 90162




66


API NC 70

9

9 1/4

9 1/2

9 3/4

10

10 1/4

API NC 77

10

10 1/4

10 1/2

10 3/4

11

7 H 904

8

8 1/4

8 1/2

7 5/8 API Regular

8 1/2

8 3/4

9

9 1/4

9 1/2

7 5/8 H 904

9

9 1/4

9 1/2




67

Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4*75,800 *75,800 *75,800 *75,800 *75,800*101686 *101686 *101686 *101686 *101686

*88,800 *88,800 *88,800 *88,800 *88,800*119312 *119312 *119312 *119312 *119312

*102,400 *102,400 101,100 96,200 91,000*136938 *136938 135582 128803 122024

108,800 105,700 101,100 96,200 91,000145073 142361 135582 128803 122024

108,800 105,700 101,100 96,200 91,000145073 142361 135582 128803 122024

108,800 105,700 101,100 96,200 91,000145073 142361 135582 128803 122024

*108,200 *108,200 *108,200 *108,200*145073 *145073 *145073 *145073

*124,100 *124,100 *124,100 *124,100*165410 *165410 *165410 *165410

*140,500 *140,500 135,100 129,400*187103 *187103 180324 173545

145,500 140,500 135,100 129,400193882 187103 180324 173545

145,500 140,500 135,100 129,400193882 187103 180324 173545

*53,500 *53,500 *53,500 *53,500*71858 *71858 *71858 *71858

*63,700 *63,700 *63,700 61,000*85417 *85417 *85417 *82027

72,100 69,300 69,300 61,00096941 92874 88128 82027

*60,400 *60,400 *60,400 *60,400*81349 *81349 *81349 *81349

*72,200 *72,200 *72,200 *72,200*96263 *96263 *96263 *96263

*84,400 *84,200 79,500 74,500*112533 *112533 107110 100331

88,600 84,200 79,500 74,500119312 112532 107110 100331

88,600 84,200 79,500 74,500119312 112532 107110 100331

*73,000 *73,000 *73,000 *73,000*97619 *97619 *97619 *97619

*86,000 *86,000 *86,000 *86,000*115922 *115922 *115922 *115922

*99,500 *99,500 *99,500 96,300*132870 *132870 *132870 129481




68


Notes: Torque figures preceded by an asterisk indicate that the weaker member for the corresponding out-side diameter (OD) and bore is the BOX. For all other torque values the weaker member is the PIN.

Normal torque range is tabulated value plus 10%. Higher torque values may be used under extreme conditions.


8 5/8 API Regular

10

10 1/4

10 1/2

8 5/8 H 904

10 1/4

10 1/2

7

H 904

(with low

torque face)

8 3/4

9

7 5/8

API Regular

(with low

torque face)

9 1/4

9 1/2

9 3/4

10

7 5/8

H 904

(with low

torque face)

9 3/4

10

10 1/4

10 1/2

8 5/8

API Regular

(with low

torque face)

10 3/4

11

8 5/8

H 904

(with low

torque face)

10 3/4

11

11 1/4


69

Bore of Drill Collar (in)2 13/16 3 3 1/4 3 1/2 3 3/4

*109,300 *109,300 *109,300 *109,300*146428 *146428 *146428 *146428

*125,300 *125,300 *125,300 *125,300*166766 *166766 *166766 *166766

141,100 136,100 130,800 125,000188459 181680 174901 166766

*113,500 *113,500 *113,500 *113,500*152530 *152530 *152530 *152530

*130,100 *130,100 *130,100 *130,100*174223 *174223 *174223 *174223

*68,100 *68,100 67,300 62,800*91518 *91518 90162 84061

74,200 71,400 67,300 62,800100331 96263 90162 84061

*73,100 *73,100 *73,100 *73,100*97619 *97619 *97619 *97619

*86,500 *86,500 82,500 77,300*115245 *115245 111177 104398

91,800 87,300 82,500 77,300123379 117956 111177 104398

91,800 87,300 82,000 77,300123379 117956 111177 104398

*91,700 *91,700 *91,700 *91,700*123379 *123379 *123379 *123379

*106,300 *106,300 104,200 98,800*142361 *142361 140327 132870

113,900 109,200 104,200 98,800152530 146428 140327 132870

113,900 109,200 104,200 98,800152530 146428 140327 132870

*112,900 *112,900 *112,900 *112,900*151852 *151852 *151852 *151852

*130,700 *130,700 *130,700 *130,700*174901 *174901 *174901 *174901

*93,000 *93,000 *93,000 *93,000*125413 *125413 *125413 *125413

*110,800 *110,800 *110,800 *110,800*149140 *149140 *149140 *149140

*129,200 *129,200 *129,200 *129,200 *173545 *173545 *173545 *173545

Notes: 1. Basis of calculations for recommended make-up torque assumed the use of a thread compound containing a 0.08 coefficient of friction, applied thoroughly to all threads and shoulders, and using the modified Jack Screw formula in Appendix A, paragraph A.8 and a unit stress of 62,500 psi in the box or pin, whichever is weaker.

2. In each connection size and type group, torque values apply to all connection types in the group, when used with the same drill collar outside diameter and bore, i.e. 2 3/8, API IF, API NC 26, and 2 7/8 Slim Hole connections used with 3 1/2 x 1 1/4 drill collars all have the same minimum make-up torque of 4,600 ft-lb, and the BOX is the weaker member.

3. Make-up torque for 2 7/8 PAC connection is based on 87,500 psi stress and other factors listed in note 1.

4. Make-up torque for H-90 connection is based on 56,200 psi stress and other factors listed in note 1.



70

Drill Collar Spiral Options

Drill Collar

30”

3”

24”

Drill Collar with Zip Grooves

Drill Collar with Hardband Grooves

and Zip Grooves

30”

3”


71

Hardbanding


72

Drill Collar Weight per Unit of Measurelb/ft, kg/m

Drill Collar OD (in)

Drill Collar ID (in)

1 1 1/4 1 1/2 1 3/4 2

2 7/8lbs/ft 19 18 16kg/m 28 27 24

3lbs/ft 21 20 18kg/m 31 30 27

3 1/8lbs/ft 22 22 20kg/m 33 33 30

3 1/4lbs/ft 26 24 22kg/m 39 36 33

3 1/2lbs/ft 30 29 27kg/m 45 43 40

3 3/4lbs/ft 35 33 32kg/m 52 49 48

4lbs/ft 40 39 37 35 32kg/m 60 58 55 52 48

4 1/8lbs/ft 43 41 39 37 35kg/m 64 61 58 55 52

4 1/4lbs/ft 46 44 42 40 38kg/m 68 65 62 60 56

4 1/2lbs/ft 51 50 48 46 43kg/m 76 74 71 68 64

4 3/4lbs/ft 54 52 50kg/m 80 77 74

5 lbs/ft 61 59 56kg/m 91 88 83

5 1/4lbs/ft 68 65 63kg/m 101 97 94

5 1/2lbs/ft 75 73 70kg/m 112 108 104

5 3/4lbs/ft 82 80 78kg/m 122 119 116

6lbs/ft 90 88 85kg/m 134 131 126

6 1/4lbs/ft 98 96 94kg/m 146 143 140

6 1/2lbs/ft 107 105 102kg/m 159 156 152

6 3/4lbs/ft 116 114 111kg/m 172 170 165

7lbs/ft 125 123 120kg/m 186 183 179

7 1/4lbs/ft 134 132 130kg/m 199 196 193

7 1/2lbs/ft 144 142 139kg/m 214 211 207

7 3/4lbs/ft 154 152 150kg/m 229 226 223


73

Drill Collar ID (in)

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

2943

3248

3552

4161

47 4470 65

53 5079 74

60 5789 85

67 64 60100 95 89

75 72 67 64 60112 107 100 95 89

83 79 75 72 68124 118 111 107 101

91 88 83 80 76 72135 131 123 119 113 107

99 96 91 89 85 80147 143 135 132 126 119

108 105 100 98 93 89161 156 149 146 138 132

117 114 110 107 103 98 93 84174 170 163 159 153 146 138 125

127 124 119 116 112 108 103 93189 184 177 172 166 161 153 138

137 133 129 126 122 117 113 102204 198 192 187 181 174 168 152

147 144 139 136 132 128 123 112218 214 207 202 196 190 183 166

Pound per footKilogram per meter

Notes: Refer to API spec 7-1 Latest Edition for API standard drill collar dimensions. For special configurations of drill collars, consult the manufacturer for reduction in weight.


74

Drill Collar Weight

30 ft (lb), 31 ft (kg)


Drill Collar ID (in)1 1 1/4 1 1/2 1 3/4 2

8lbs/ft 165 163 160kg/m 245 242 238

8 1/4lbs/ft 176 174 171kg/m 262 257 254

8 1/2lbs/ft 187 185 182kg/m 278 275 270

9lbs/ft 210 208 206kg/m 312 309 306

9 1/2lbs/ft 234 232 230kg/m 348 345 342

9 3/4lbs/ft 248 245 243kg/m 369 364 361

10lbs/ft 261 259 257kg/m 388 385 382

11lbs/ft 317 315 313kg/m 471 468 465

12lbs/ft 379 377 374kg/m 563 560 557

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



2 7/8lbs 589 558 496kg 267 253 225

3lbs 651 620 558kg 295 281 253

3 1/8lbs 682 682 620kg 309 309 281

3 1/4lbs 806 744 682kg 365 337 309

3 1/2lbs 930 899 837kg 422 407 400

3 3/4lbs 1,085 1,023 992kg 492 463 450

4lbs 1,240 1,209 1,147 1,085 992kg 562 548 520 492 450

4 1/8lbs 1,333 1,271 1,209 1,147 1,085kg 604 577 548 520 492

4 1/4lbs 1,426 1,364 1,302 1,240 1,178kg 647 619 590 562 534


75

Drill Collar ID (in)2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4157 154 150 147 143 138 133 122233 229 223 218 213 205 198 181

168 165 160 158 154 149 144 133250 245 238 235 229 221 214 198

179 176 172 169 165 160 155 150266 262 256 251 245 238 230 223

203 200 195 192 188 184 179 174302 297 290 285 279 273 266 259

227 224 220 216 212 209 206 198337 333 327 321 315 311 306 294

240 237 232 229 225 221 216 211357 352 345 340 334 328 321 314

254 251 246 243 239 235 230 225377 373 366 361 355 349 342 334

310 307 302 299 295 291 286 281461 456 449 444 438 432 425 418

371 368 364 361 357 352 347 342551 547 541 537 531 523 516 508

Notes (cont): 2. For special configurations of drill collars, consult manufacturer for reduction in weight.

Drill Collar ID (in)2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 4

899407

992450

1,085492

Pound per footKilogram per meter

PoundKilogram

Notes: Refer to API spec 7-1 Latest Edition for API standard drill collar dimensions. For special configurations of drill collars, consult the manufacturer for reduction in weight.


76

Drill Collar Weight31 ft (lb), 31 ft (kg)

Notes: 1. Refer to API Spec. 7-1 Latest Edition. Latest Edition for API standard drill collar dimensions. 2. For special configurations of drill collars, consult manufacturing for reduction in weight.

Drill Collar OD(in)


4 1/2lbs 1,581 1,550 1,488 1,426 1,333kg 717 703 675 646 604

4 3/4lbs 1,674 1,612 1,550kg 759 731 703

5lbs 1,891 1,829 1,736kg 857 829 787

5 1/4lbs 2,108 2,015 1,953kg 956 913 885

5 1/2lbs 2,325 2,263 2,170kg 1055 1026 984

5 3/4lbs 2,542 2,480 2,418kg 1152 1125 1097

6lbs 2,790 2,728 2,635kg 1266 1237 1195

6 1/4lbs 3,038 2,976 2,914kg 1378 1350 1322

6 1/2lbs 3,317 3,255 3,162kg 1505 1476 1434

6 3/4lbs 3,596 3,534 3,441kg 1631 1603 1561

7lbs 3,875 3,813 3,720kg 1758 1730 1687

7 1/4lbs 4,154 4,092 4,030kg 1884 1856 1828

7 1/2lbs 4,464 4,402 4,309kg 2025 1997 1955

7 3/4lbs 4,774 4,712 4,650kg 2165 2137 2109

8lbs 5,115 5,053 4,960kg 2320 2292 2250

8 1/4lbs 5,456 5,394 5,301kg 2475 2447 2404

8 1/2lbs 5,797 5,735 5,642kg 2629 2601 2559

9lbs 6,510 6,448 6,386kg 2953 2925 2897

9 1/2lbs 7,254 7,192 7,130kg 3290 3262 3234

9 3/4lbs 7,688 7,595 7,533kg 3487 3445 3417

10lbs 8,091 8,029 7,967kg 3670 3642 3614

11lbs 9,827 9,765 9,703kg 4457 4429 4401

12lbs 11,749 11,687 11,594kg 5329 5301 5259


77

2 1/4 2 1/2 2 13/16 3 3 1/4 3 1/2 3 3/4 41,271

576

1,457 1,364660 618

1,643 1,550745 703

1,860 1,767843 801

2,077 1,984 1,860942 899 843

2,325 2,232 2,077 1,984 1,8601055 1012 942 899 843

2,573 2,449 2,325 2,232 2,1081167 1111 1055 1012 956

2,821 2,728 2,573 2,480 2,356 2,2321280 1237 1167 1125 1069 1012

3,069 2,976 2,821 2,759 2,635 2,4801392 1350 1280 1251 1195 1125

3,348 3,255 3,100 3,038 2,883 2,7591519 1476 1406 1378 1308 1252

3,627 3,534 3,410 3,317 3,193 3,038 2,883 2,6041645 1603 1547 1505 1448 1378 1308 1181

3,937 3,844 3,689 3,596 3,472 3,348 3,193 2,8831786 1744 1673 1631 1575 1519 1448 1308

4,247 4,123 3,999 3,906 3,782 3,627 3,503 3,1621926 1870 1814 1772 1715 1645 1589 1434

4,557 4,464 4,309 4,216 4,092 3,968 3,813 3,4722067 2024 1955 1912 1856 1800 1730 1575

4,867 4,774 4,650 4,557 4,433 4,278 4,123 3,7822208 2165 2109 2067 2011 1940 1870 1715

5,208 5,115 4,960 4,898 4,774 4,619 4,464 4,1232362 2320 2250 2222 2165 2095 2025 1870

5,549 5,456 5,332 5,239 5,115 4,960 4,805 4,6502517 2475 2419 2376 2320 2250 2180 2109

6,293 6,200 6,045 5,952 5,828 5,704 5,549 5,3942854 2812 2742 2700 2644 2587 2517 2447

7,037 6,944 6,820 6,696 6,572 6,479 6,386 6,1383192 3150 3093 3037 2981 2939 2897 2784

7,440 7,347 7,192 7,099 6,975 6,851 6,696 6,5413375 3333 3262 3220 3164 3108 3037 2967

7,874 7,781 7,626 7,533 7,409 7,285 7,130 6,9753572 3529 3459 3417 3361 3304 3234 3164

9,610 9,517 9,362 9,269 9,145 9,021 8,866 8,7114359 4317 4247 4204 4148 4092 4022 3951

11,501 11,408 11,284 11,191 11,067 10,912 10,757 10,6025217 5175 5118 5076 5020 4950 4879 4809

PoundKilogram


78

Drill Collar Bending Strength Ratios

1 1/2" ID


79

To obtain bending strength

ratio, measure OD & ID of drill

collar ar points shown in the

illustration.

1 3/4" ID


80


2" ID


81



collar at points shown in the

illustration.

2 1/4" ID


82


2 1/2" ID


83




illustration.

2 1/2" ID


84


2 13/16" ID


85




illustration.

2 13/16" ID


86


3" ID


87




illustration.

3" ID


88


3 1/4" ID


89




illustration.

3 1/4" ID


90


3 1/2" ID


91




illustration.

3 1/2" ID


92

API Interchangeable Connection Table

Connection Name Size

Numbered Connection (NC) 26 31 38 40 46 50

Internal Flush (IF) 2 3/8 2 7/8 3 1/2 4 4 1/2

Slim Hole (SH) 2 7/8 3 1/2 4 4 1/2

Full Hole (FH) 4

Double Streamline (DSL) 3 1/2 4 1/2 5 1/2

Extra Hole (XH) 2 7/8 3 1/2 4 1/2 5

External Flush (EF) 4 1/2


93

Notes: 1. The minimum size drill collar, calculated from the Lubinski and Hock equation, with the specific sizes of

hole and casing combination, is too large for conventional fishing tools. When the minimum drill collar diameter is too large to washover and/or catch with an overshot, other steps should be taken. Some of the possibilities are as follows:

• Use turned down casing couplings. • Use integral joints on casing. • Under-ream the hole. • Run smaller size casing.

2. Use a packed hole assembly instead of a pendulum.3. Not API standard size drill collar.

Ideal Drill Collar Range

Hole Size (in)

Casing Size To Be Run

(in)

Ideal Collar Drill Range API Drill Collar

Min.(in)

Max. (in)

Sizes Which Fall in the Ideal Range (in)

6 1/8 4 1/2 3.875 4.750 4 1/8, 4 3/4

6 1/4 4 1/2 3.750 4.875 4 1/8, 4 3/4

6 3/4 4 1/2 3.250 5.125 3 1/2, 4 1/8, 4 3/4, 5

7 7/84 1/2 2.125 6.250 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4

5 1/2 4.225 6.250 4 3/4, 5, 6, 6 1/4

8 3/85 1/2 3.725 6.750 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4

6 5/8 6.405 6.750 6 1/2, 6 3/4

8 1/26 5/8 6.280 6.750 6 1/2, 6 3/4

7 6.8121 6.750 6 3/4

8 3/46 5/8 6.030 7.125 6 1/4, 6 1/2, 6 3/4, 7

7 6.562 7.125 6 3/4, 7

9 1/27 5.812 7.625 6, 6 1/4, 6 1/2, 7, 7 1/4

7 5/8 7.500 7.875 7 3/4

9 7/87 5.437 8.000 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8

7 5/8 7.125 8.000 7 1/4, 7 3/4, 8

10 5/87 5/8 6.375 8.500 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4

8 5/8 8.6252 8.500 8 1/4

11 8 5/8 8.250 8.875 8 1/4

12 1/49 5/8 9.000 10.125 9, 9 1/2, 9 3/4, 10

10 3/4 11.2502 10.125 10

13 3/4 10 3/4 9.750 11.250 9 3/4, 10, 11

14 3/4 11 3/4 10.750 12.000 11, 12

17 1/2 13 3/8 11.250 13.375 123

20 16 14.000 14.750 143

24 18 5/8 15.500 16.750 163

26 20 16.000 19.500 163


94

Tong Type

Jaw Sizes (in)

Capacity (ft-lbs) Applicable API Drill Collar Sizes (in)

B.J. HUGHES COMPANY

SXD 8 - 16 200,000 8, 8 1/4, 9, 9 1/2, 9 3/4, 10, 11

SDD 4 - 12 100,0004 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4,7, 7 1/4, 7 3/4, 8, 8 1/4, 9, 9 1/2, 9 3/4, 10

DB 3 1/2 - 11 1/4 65,0003 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4

B 3 1/2 - 9 55,000 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8

C 2 3/8 - 10 3/4 35,000 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6,6 1/4, 6 1/2, 6 3/4

F 2 3/8 - 10 3/4 25,000 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6

JOY-WEB WILSON COMPANY

ST-160 7 1/2 - 12 160,000 7 3/4, 8, 8 1/4, 9, 9 1/2, 9 3/4, 10 11

ST-60 4 - 9 5/8 60,000 4 1/8,, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4,7, 7 1/4, 7 3/4, 8

H 3 1/2 - 10 3/4 80,0003 1/2, 4 1/8, 4 3/4, 5, 6, 61/4,6 1/2, 7, 7 1/4, 7 3/4, 8, 8 1/4, 9

AAX 2 7/8 - 7 1/4 55,0003 1/8, 3 1/2, 4 1/8,, 4 3/4,, 5, 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 8

B 2 3/8 - 8 5/8 35,000 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4

WOOLLEY COMPANY

SDD 4 - 12 100,0004 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4, 9, 9 1/2, 9 3/4, 10

SUPER A 3 1/2 - 11 1/4 65,0003 1/2,, 4 1/4, 4 3/4 ,5, 6, 6 1/4, 6 1/2, 6 3/4, 7, 7 1/4, 7 3/4, 8, 8 1/4

SUPER B 1/2 - 9 55,000 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 7, 7 1/4, 8

SUPER C 2 3/8 - 7 35,000 3 1/8, 3 1/2, 4 1/8, 4 3/4, 5, 6, 6 1/4, 6 1/2, 6 3/4

Rig Tongs


SU

BS

AN

DK

EL

LY

S

Subs and Kellys

95

Types of Subs


96

Subs

1. Other lengths may be specified by the customer, example 48 inches.

2. Fishing neck (tong space) length, unless specified otherwise, is one

half the overall length of the sub. For example, 18 inch fishing neck

(tong space) on a 36 inch sub; 24 inch on a 48 inch sub.

3. Bevel Diameters:

A. If the connection is to screw onto a piece of Drill Pipe (pipe, D/P)

use the bevel diameters listed on drawing HB1003 in the “Bevel

Dia.” section of the Machining Handbook.

B. If the connection is a Bit Box (with or without a float bore) use the

bevel diameters listed in column B in the top chart of drawing

HB1017 “Float Bore” in this section of the Machining Handbook.

C. If the connection is to screw onto a Drill Collar (Collar, D/C) use

the bevel diameters listed at the bottom of the drawing of the

specified connection.

4. Float bore not applicable for double-shouldered connections

General Notes on Subs

Crossover Sub


97

Kelly Saver Subs

TAB 5 RSHandbook_SubsKellys.indd 97TAB 5 RSHandbook_SubsKellys.indd 97 11/18/2010 5:38:14 PM11/18/2010 5:38:14 PM

98

Bit Sub

Lift Sub


99

Bit Box Float Bores

Box Up Float Bores


100

Kelly Weights – Pounds Per FootDrive Section Only

Hexagon Kelly

Square Kelly

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

3 26.4 24.6 22.4

3 1/2 35.6 33.5 31.0 28.1

4 1/4 47.9 44.7 41.2 40.3

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

3 22.3 20.5

3 1/2 30.1 27.9 25.4 22.5

4 1/4 39.7 36.5 33.0 32.1

5 1/4 61.0 60.0 57.1 52.9


101

Nom

inal

Si

ze

Avai

labl

e Le

ngth

s (ft

)(A

)

Top U

pset

Join

tBo

ttto

m U

pset

Bore (E)

Driv

e Sec

tion

Appr

ox.

wt.

per

40 ft

(lbs

.)AP

I Box

Thre

adLe

ft Ha

nd

OD (C)

Righ

t Ha

ndCo

nnec

tions

OD (D)

Acro

ssCo

rner

s (F

)

Acro

ss

Flat

s(G

)

340

, 60

6 5/

8 Re

g.7

3/4

NC3

1(2

7/8I

F)4

1/8

1 3/

43.

875

310

904

1/2

Reg.

5 3/

4

3 1/

240

, 60

6 5/

8 Re

g.7

3/4

NC3

8(3

1/2I

F)4

3/4

2 1/

44.

437

3 1/

213

004

1/2

Reg.

5 3/

4

4 1/

440

, 60

6 5/

8 Re

g.7

3/4

NC4

6(4

IF)1

6 1/

42

13/1

65.

500

4.25

1830

4 1/

2 Re

g.5

3/4

NC5

0(4

1/2I

F)1

6 3/

8

Note

s:1.

The

low

er en

d of 4

1/4 a

nd 5

1/4 s

quar

e kel

lys h

ave t

wo s

tand

ard s

izes a

nd st

yles

of c

onne

ctio

ns.

2. A

ll di

men

sion

in in

ches

unl

ess o

ther

wise

spec

ified

.3.

Sho

rt b

oreb

ack s

tand

ard i

n to

p box

.

Square Kelly


102

Hexagonal KellyNo

min

al

Size

Avai

labl

e Le

ngth

s (ft

)(A

)

Top U

pset

Join

tBo

ttto

m U

pset

Bore (E)

Driv

e Sec

tion

Appr

ox.

wt.

per

40 ft

(lbs

.)AP

I Box

Thre

adLe

ft Ha

nd

OD (C)

Righ

t Ha

ndCo

nnec

tions

OD (D)

Acro

ssCo

rner

s (F

)

Acro

ss

Flat

s(G

)

340

, 60

6 5/

8 Re

g.7

3/4

NC2

6 (2

3/8

IF)

3 3/

81

1/2

3.37

53

1000

4 1/

2 Re

g.5

3/4

3 1/

240

, 60

6 5/

8 Re

g.7

3/4

NC3

1(2

7/8I

F)4

1/8

1 3/

43.

937

3 1/

212

904

1/2

Reg.

5 3/

4

4 1/

440

, 60

6 5/

8 Re

g.7

3/4

NC3

8(3

1/2I

F)4

3/4

2 1/

4 4.

781

4.25

1730

4 1/

2 Re

g.5

3/4

5 1/

440

, 60

6 5/

8 Re

g.7

3/4

NC4

6(4

IF)*

6 1/

42

13/1

6

5.90

05

1/4

2560

3

NC5

0(4

1/2I

F)*

6 3/

83

1/4

Note

s:1.

The

low

er en

d of 4

1/4 a

nd 5

1/4 s

quar

e kel

lys h

ave t

wo s

tand

ard s

izes a

nd st

yles

of c

onne

ctio

ns.

2. A

ll di

men

sion

in in

ches

unl

ess o

ther

wise

spec

ified

.3.

Sho

rt b

oreb

ack s

tand

ard i

n to

p box

.


103

Under ideal conditions, a new Drive Bushing assembly should be used

when picking up a new kelly. If this is not possible, the following check-

list should be performed:

1. Inspect surfaces on Drive Bushing rollers for wear. Example: For a

5 1/4 inch Hex, if wear exceeds 1/8 inch, reverse the rollers.

2. Check clearance between roller face and side of kelly. Example: For

a 5 1/4 inch Hex, if clearance is more than 1/8 inch, inspect roller

assembly and Kelly Bushing for excessive wear.

3. Inspect bottom taper of Drive Pins for wear and damage. Replace

as necessary.

4. Inspect for clearance between upper and lower halves, replace if

clearance is zero.

Note: A worn out Drive Bushing can severely damage a new kelly.

Picking Up a New Kelly


104

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

____________________________________________

Notes


Well Control

Height of Kick (ft) = Pit Gain ÷ Annular Capacity in Bbls/ft

Density of Kick Fluids (ppg) = MW – [(SICP-SIDPP) ÷ Height of Kick ÷

0.052]

Approximate Typical Fluid Densities: Gas-2ppg, Oil-7ppg, Water-9ppg

Lag Time Rule of Thumb: Pressure changes from choke movement will take

about two seconds per 1000’ of depth to travel down the annulus and up

the drill pipe to the DP gauge.

Sacks of Barite needed to Weight-Up Mud = Bbls Mud x 14.7 x (KWM-

OWM) ÷ (35.4-KWM)

Volume Increase in Bbls from adding Barite = Sacks Added ÷ 14.9

Volume Increase in Bbls from adding Barite = (Gel) = Sacks Added ÷ 8.75

Triplex Pump Output (bbls/stk @ 100%) = 0.000243 x Stroke Length x

(Liner Dia)2

Duplex Pump Outlet (bbl/stk @ 100%) = 0.000162 x Stroke x

[(2 x Liner Dia2) - Rod Dia2]

Annular Capacity (bbls/ft) = (ID2hole - OD2pipe) ÷ 1029

105

WELL CO

NTRO

L


Well Control

MW Mud Weight

SICP Shut in casing pressure

SIDPP Shut in drill pipe pressure

ppg Pounds per gallon

KWM Kill Weight Mud

OWM Original Weight Mud

DP Drill Pipe

Bbls Barrels

Stk Stroke

106

Capacity of DUPLEX Mud Pumps at 100% Efficiency

Liner Dia Stroke Length (in)

(in) 12 14 16 18

4 1/2 0.074 0.082 – –

5 0.089 0.104 0.113 0.128

5 1/2 0.110 0.128 0.141 0.158

6 – 0.154 0.170 0.192

6 1/2 – 0.183 0.203 0.228

7 – 0.213 0.238 0.267

7 1/2 – 0.241 0.275 0.310

(in Bbls/stroke)

Capacity of TRIPLEX Mud Pumps at 100% Efficiency

Liner Dia Stroke Length (in)

(in) 9 10 11 12

5 0.055 0.061 0.067 0.073

5 1/2 0.066 0.074 0.081 0.088

6 0.079 0.087 0.096 0.105

6 1/2 0.092 0.103 0.113 0.123

7 0.107 0.119 0.131 0.143

7 1/2 0.123 0.137 0.150 0.164

(in Bbls/stroke)

107

SizeOD

SizeID

NominalWeight Capacity Displacement

(in) (in) (lb/ft) (bbl/ft) (bbl/ft)

2 3/8 1.81 6.6 0.0032 0.0028

2 7/8 2.15 10.4 0.0045 0.0041

3 1/2 2.76 13.3 0.0074 0.0051

3 1/2 2.60 15.5 0.0066 0.0058

4 3.34 14.0 0.0108 0.0057

4 1/2 3.82 16.6 0.0142 0.0064

4 1/2 3.64 20.0 0.0129 0.0077

5 4.28 19.5 0.0178 0.0075

5 1/2 4.78 21.9 0.0222 0.0087

5 1/2 4.67 24.7 0.0211 0.0096

6 5/8 4.86 22.2 0.0229 0.0087

6 5/8 5.96 25.2 0.0346 0.0098

API Standard Drill Pipe Capacity and Displacement


SizeOD

SizeID Weight Capacity Displacement

(in) (in) (lb/ft) (bbl/ft) (bbl/ft)

3 1/2 2.0625 25.3 0.00421 0.00921

4 2.5625 29.7 0.00645 0.01082

4 1/2 2.75 41.0 0.00743 0.01493

5 3.0 49.3 0.00883 0.01796

5 1/2 3.25 61.5 0.01030 0.02240

6 5/8 4.5 72.0 0.01970 0.02620

Additional capacities, displacements and weight can be determined from the following formulas:

CAPACITY = = bbls/ft

DISPLACEMENT = = bbls/ft

WEIGHT = DISPLACEMENT bbls/ft x 2747 lbs/bbl = lbs/ft

ID2

1029.4

OD2 - ID2

1029.4

TAB 6 RSHandbook_WellControl.indd 107TAB 6 RSHandbook_WellControl.indd 107 11/18/2010 5:37:53 PM11/18/2010 5:37:53 PM

108

Drill

Colla

r Cap

acity

and D

ispla

cem

ent (

bbls/

ft)OD

ID1 1

/21 3

/42

2 1/4

2 1/2

2 3/4

33 1

/43 1

/23 3

/44

4 1/4

(in)

Cap

0.00

220.

0030

0.00

390.

0049

0.00

610.

0073

0.00

870.

0103

0.01

190.

0137

0.01

550.

0175

4lb

/ft

36.7

34.5

32.0

29.2

--

--

--

--

Dis

p.0.

0133

0.01

250.

0116

0.10

6-

--

--

--

-

4 1/

4lb

/ft

42.4

40.0

37.5

34.7

--

--

--

--

Dis

p.0.

0153

0.01

450.

0136

0.01

26-

--

--

--

-

4 1/

2lb

/ft

48.1

45.9

43.4

40.6

--

--

--

--

Dis

p.0.

175

0.01

670.

0158

0.01

48-

--

--

--

-

4 3/

4lb

/ft

54.3

52.1

49.6

46.8

43.6

--

--

--

-

Dis

p.0.

0197

0.01

890.

0181

0.01

700.

0159

--

--

--

-

5lb

/ft

60.8

58.6

56.1

53.3

50.1

--

--

--

-

Dis

p.0.

0221

0.02

130.

0204

0.01

940.

0182

--

--

--

-

5 1/

4lb

/ft

67.6

65.4

62.9

60.1

56.9

53.4

--

--

--

Dis

p.0.

0246

0.02

380.

0229

0.02

190.

0207

0.01

94-

--

--

-

5 1/

2lb

/ft

74.8

72.6

70.1

67.3

64.1

60.6

56.8

--

--

-

Dis

p.0.

0272

0.02

640.

0255

0.02

450.

0233

0.02

210.

0207

--

--

-

5 3/

4lb

/ft

82.3

80.1

77.6

74.8

71.6

68.1

64.3

--

--

-

Dis

p.0.

0299

0.02

910.

0282

0.02

720.

0261

0.02

480.

0234

--

--

-

6lb

/ft

90.1

87.9

85.4

82.6

79.4

75.9

72.1

67.9

63.4

--

-

Dis

p.0.

0328

0.03

200.

0311

0.03

010.

0289

0.02

760.

0262

0.02

470.

0231

--

-

6 1/

4lb

/ft

98.0

95.8

93.3

90.5

87.3

83.8

80.0

75.8

71.3

--

-

Dis

p.0.

0356

0.03

490.

0339

0.03

290.

0318

0.03

050.

0291

0.02

760.

0259

--

-

6 1/

2lb

/ft

107.

010

4.8

102.

399

.596

.392

.889

.084

.880

.3-

--

Dis

p.0.

0389

0.03

810.

0372

0.03

620.

0350

0.03

380.

0324

0.03

080.

0292

--

-


109

Drill

Colla

r Cap

acity

and D

ispla

cem

ent (

bbls/

ft) (C

ont.)

ODID

1 1/2

1 3/4

22 1

/42 1

/22 3

/43

3 1/4

3 1/2

3 3/4

4 4 1

/4(in

)Ca

p0.

0022

0.00

300.

0039

0.00

490.

0061

0.00

730.

0087

0.01

030.

0119

0.01

370.

0155

0.01

75

6 3/

4lb

/ft

116.

011

3.8

111.

310

8.5

105.

310

1.8

98.0

93.8

89.3

--

-

Dis

p.0.

0422

0.04

140.

0405

0.03

950.

0383

0.03

700.

0356

0.03

410.

0325

--

-

7lb

/ft

125.

012

2.8

120.

311

7.5

114.

311

0.8

107.

010

2.8

98.3

93.4

88.3

-

Dis

p.0.

0455

0.04

470.

0438

0.04

270.

0416

0.04

030.

0389

0.03

740.

0358

0.03

400.

0321

-

7 1/

4lb

/ft

134.

013

1.8

129.

312

6.5

123.

311

9.8

116.

011

1.8

107.

310

2.4

97.3

-

Dis

p.0.

0487

0.04

790.

0470

0.04

600.

0449

0.04

360.

0422

0.04

070.

0390

0.03

720.

0354

-

7 1/

2lb

/ft

144.

014

1.8

139.

313

6.5

133.

312

9.8

126.

012

1.8

117.

311

2.4

107.

3-

Dis

p.0.

0524

0.05

160.

0507

0.04

970.

0485

0.04

720.

0458

0.04

430.

0427

0.04

090.

0390

-

7 3/

4lb

/ft

154.

015

1.8

149.

314

6.5

143.

313

9.8

136.

013

1.8

127.

312

2.4

117.

3-

Dis

p.0.

0560

0.05

520.

0543

0.05

330.

0521

0.05

090.

0495

0.04

790.

0463

0.04

450.

0427

-

8lb

/ft

165.

016

2.8

160.

315

7.5

154.

315

0.8

147.

014

2.8

138.

313

3.4

123.

312

2.8

Dis

p.0.

0600

0.05

920.

0583

0.05

730.

0561

0.05

490.

0535

0.05

200.

0503

0.04

850.

0467

0.04

47

8 1/

4lb

/ft

176.

017

3.8

171.

316

8.5

165.

316

1.8

158.

015

3.8

149.

314

4.4

139.

313

3.8

Dis

p.0.

0640

0.06

320.

0623

0.06

130.

0601

0.05

890.

0575

0.05

600.

0543

0.05

250.

0507

0.04

87

8 1/

2lb

/ft

187.

018

4.8

182.

317

9.5

176.

317

2.8

169.

016

4.8

160.

315

5.4

150.

314

4.8

Dis

p.0.

0680

0.06

720.

0663

0.06

530.

0641

0.06

290.

0615

0.06

000.

0583

0.05

650.

0547

0.05

27

8 3/

4lb

/ft

199.

019

6.8

194.

319

1.5

188.

318

4.8

181.

017

6.8

172.

316

7.4

162.

315

6.8

Dis

p.0.

0724

0.07

160.

0707

0.06

970.

0685

0.06

720.

0658

0.06

430.

0697

0.06

090.

0590

0.05

70

9lb

/ft

210.

220

8.0

205.

620

2.7

199.

619

6.0

192.

218

8.0

183.

517

8.7

173.

516

8.0

Dis

p.0.

0765

0.07

570.

0748

0.07

380.

0726

0.07

140.

0700

0.06

850.

0668

0.06

510.

0632

0.06

12

10lb

/ft

260.

925

8.8

256.

325

3.4

250.

324

6.8

242.

923

8.8

234.

322

9.4

224.

221

8.7

Dis

p.0.

0950

0.09

420.

0933

0.09

230.

0911

0.08

980.

0884

0.08

690.

0853

0.08

350.

0816

0.07

96


110

Buoyancy Factors

Mud Density BuoyancyFactor (Kb)(lb/gal) (lb/cu ft) (g/cc)

8.4 62.84 1.01 0.872

8.6 64.33 1.03 0.869

8.8 65.83 1.05 0.866

9.0 67.32 1.08 0.862

9.2 68.82 1.10 0.859

9.4 70.32 1.12 0.856

9.6 71.81 1.15 0.853

9.8 73.31 1.17 0.850

10.0 74.80 1.20 0.847

10.2 76.30 1.22 0.844

10.4 77.80 1.24 0.841

10.6 79.29 1.27 0.838

10.8 80.79 1.29 0.835

11.0 82.29 1.32 0.832

11.2 83.78 1.34 0.829

11.4 85.28 1.36 0.826

11.6 86.77 1.39 0.823

11.8 88.27 1.41 0.820

12.0 89.77 1.44 0.817

12.2 91.26 1.46 0.814

12.4 92.76 1.48 0.811

12.6 94.25 1.51 0.807

12.8 95.75 1.53 0.804

13.0 97.25 1.56 0.801

13.2 98.74 1.58 0.798

13.4 100.24 1.60 0.795

13.6 101.74 1.63 0.792

13.8 103.23 1.65 0.789


111

Mud Density BuoyancyFactor (Kb)(lb/gal) (lb/cu ft) (g/cc)

14.0 104.73 1.68 0.786

14.2 106.22 1.70 0.783

14.4 107.72 1.72 0.780

14.6 109.22 1.75 0.777

14.8 110.71 1.77 0.774

15.0 112.21 1.80 0.771

15.2 113.70 1.82 0.768

15.4 115.20 1.84 0.765

15.6 116.70 1.87 0.762

15.8 118.19 1.89 0.759

16.0 119.69 1.91 0.756

16.2 121.18 1.94 0.752

16.4 122.68 1.96 0.749

16.6 124.18 1.99 0.746

16.8 125.67 2.01 0.743

17.0 127.17 2.03 0.740

17.2 128.66 2.06 0.737

17.4 130.16 2.08 0.734

17.6 131.66 2.11 0.731

17.8 133.15 2.13 0.728

18.0 134.65 2.15 0.725

18.5 138.39 2.21 0.717

19.0 142.13 2.27 0.710

19.5 145.87 2.33 0.702

20.0 149.61 2.39 0.694


112

Formulas Used In Well Control and Drilling Operations

Calculating Pressure, psi and Pressure Gradients, psi/ft

1. Determine pressure gradient, psi/ft

(Mud Weight, ppg) x (0.052) = psi/ft

2. Determine hydrostatic pressure, psi (H.P.)

(Mud Wt., ppg) x (0.052) x (T.V.D., ft) = psi

3. Maximum allowable shut in casing pressure

Maximum Allowable Mud

Wt., ppg-

Mud Wt.in useppg

x (0.052) x (TVD, ft.) = psi


• Mud Weight, ppg (MW)

(Pressure, psi) ÷ (0.052) ÷ (TVD, ft) = Mud Weight, ppg

• Kill Weight Mud, ppg (KWM)

(SIDPP, psi) ÷ (0.052) ÷ (TVD, ft) + (O.M.W.) = Kill Wt., ppg

• Equivalent Mud Weight, ppg (EMW)

(pressure, psi) ÷ (0.052) ÷ (TVD, ft) = EMW, ppg

• Equivalent Circulating Density, ppg (ECD)

• Maximum Allowable Mud Weight, ppg (MAMW)

• Converting Pressure Gradient, psi/ft to Mud Wt, ppg

(Pressure Gradient, PSI/ft.) ÷ (0.052) = Mud Wt, ppg

OMW - original mud weight

SIDPP - shut in drill pipe pressure

TVD - true vertical depth

113

Converting Pressures, psi into mud weight, ppg

Anytime a pressure is to be converted to mud weight use the following formulas

Annular Pressure Loss, psi

÷ (0.052) ÷ (TVD, ft) + (OMW) = ECD, ppg

Leak-Off Pressure Loss, psi

÷ (0.052) ÷ (TVD, ft) +Test Mud

Weight = MAMW, ppg


© 2010 National Oilwell Varco© 2010 National Oilwell VarcoD392002466-MKT-001 Rev. 02D392002466-MKT-001 Rev. 02

O n e C o m p a n y . . . U n l i m i t e d S o l u t i o n s

CORPORATE HEADQUARTERS7909 Parkwood Circle DriveHouston, Texas 77036United StatesPhone: 713 375 3700Fax: 713 346 7687

UNITED STATESNOV Grant PridecoDrilling Products and Services400 N Sam Houston Parkway ESuite 900Houston, Texas 77060Phone: 281 878 5000Fax: 281 878 5833Toll Free: 866 472 6861

CHINA NOV Grant Prideco (Jiangsu) Drilling Products Company Ltd. No.1, Xibahe South Road, Room 2605Golden TowerChaoyang DistrictBeijing P.R. China 100028Phone: 86 10 6440 3590/3599Fax: 86 10 6440 3566Email: [email protected]

EUROPE AND AFRICA NOV Grant PridecoSuite C1 St Swithin RowAberdeen, ScotlandAB10 6DLPhone: 44 1224 597300Fax: 44 1224 589420Email: [email protected]

FAR EAST, ASIA-PACIFIC, INDIANOV Grant Prideco Singapore LtdNo. 11 Tuas Avenue 7Singapore 639266Phone: 011 65 6861 4266Fax: 011 65 6861 0117Email: [email protected]

MEXICO / LATIN AMERICANOV Grant Prideco de Mexico, SA de CVMariano Escobedo # 724-207Col. AnzuresMéxico 11590, D.F.Phone: 52 55 5531 0133Fax: 52 55 5254 7277Email: [email protected]

MIDDLE EASTNOV Grant PridecoDubai Airport Free ZoneEast Wing 2, 4th Floor, Office 2E-404DubaiUnited Arab EmiratesPhone: 971 4299 6446 Fax: 971 4299 6424Email: [email protected]

RUSSIA, FSUNOV Grant Prideco119017, Moscow, Russia,Bolshaya Ordynka, 44 Building 4, second floorPhone: 70 95 960 2404Fax: 70 95 960 2924Email: [email protected]

D o w n h o l e S o l u t i o n s

D r i l l i n g S o l u t i o n s

E n g i n e e r i n g a n d P r o j e c t M a n a g e m e n t S o l u t i o n s

L i f t i n g a n d H a n d l i n g S o l u t i o n s

P r o d u c t i o n S o l u t i o n s

S u p p l y C h a i n S o l u t i o n s

Tu b u l a r a n d C o r r o s i o n C o n t r o l S o l u t i o n s

We l l S e r v i c e a n d C o m p l e t i o n S o l u t i o n s

National Oilwell Varco has produced this brochure for general information only, and it is not intended for design purposes. Although every effort has been made to maintain the accuracy and reliability of its contents, National Oilwell Varco in no way assumes responsibility for liability for any loss, damage or injury resulting from the use of information and data herein. All applications for the material described are at the user’s risk and are the user’s responsibility.All brands listed are trademarks of National Oilwell Varco.

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