ISO 10407:1993

Petroleum and natural gas industries - Drilling and production equipment - Drill stem design and operating limits

Lays down the properties and establishes principles for the design and use. Requirements are specified in the fourteenth edition of API Recommended Practice 7G (RP 7G), August 1990, which is adopted as ISO 10407. For the purposes of international standardization, modifications have been made that are outlined.

Industries du pétrole et du gaz naturel — Étude des garnitures de forage et de leurs limites d'exploitation

General Information

• Status: Withdrawn
• Publication Date: 22-Dec-1993
• ICS: 75.180.10 - Exploratory, drilling and extraction equipment
• Technical Committee: ISO/TC 67/SC 4 - Drilling and production equipment
• Drafting Committee: ISO/TC 67/SC 4/WG 1 - Drilling equipment
• Current Stage: 9599 - Withdrawal of International Standard
• Start Date: 08-Sep-2023
• Completion Date: 13-Dec-2025

Relations

• Revised: ISO 10407-2:2008 - Petroleum and natural gas industries - Rotary drilling equipment - Part 2: Inspection and classification of used drill stem elements
• Effective Date: 15-Apr-2008

Standards Content (Sample)

INTERNATIONAL
Is0
STANDARD
First edition
1993-12-15
Petroleum and natural gas industries -
Drilling and production equipment - Drill
stem design and operating limits
Industries du p&role et du gaz nature1 - Etude des garnitures de forage
et de leurs limites d’exploitation
Reference number
IS0 10407:1993(E)
IS0 10407:1993(E)
Foreword
IS0 (the International Organization for Standardization) is a worldwide
federation of national standards bodies (IS0 member bodies). The work
of preparing International Standards is normally carried out through IS0
technical committees. Each member body interested in a subject for
which a technical committee has been established has the right to be re-
presented on that committee. International organizations, governmental
and non-governmental, in liaison with ISO, also take part in the work. IS0
collaborates closely with the International Electrotechnical Commission
(IEC) on all matters of electrotechnical standardization.
Draft International Standards adopted by the technical committees are
circulated to the member bodies for voting. Publication as an International
Standard requires approval by at least 75 % of the member bodies casting
a vote.
International Standard IS0 10407 was prepared by the American Petro-
leum Institute (API) (as RP 7G, 14th edition) and was adopted, under a
special “fast-track procedure”, by Technical Committee ISOK 67, Mate-
rials, equipment and offshore structures for petroleum and natural gas in-
dustries, in parallel with its approval by the IS0 member bodies.
Q IS0 1993
All rights reserved. Unless otherwise specified, no part of this publication may be reproduced
or utilized in any form or by any means, electronic or mechanical, including photocopying and
microfilm, without permission in writing from the publisher.
International Organization for Standardization
Case Postale 56 l CH-1211 Geneve 20 l Switzerland
Printed in Switzerland
ii
Q IS0
IS0 10407:1993(E)
Introduction
International Standard IS0 10407:1993 reproduces the content of
API RP 7G, 14th edition, 1990. ISO, in endorsing this API document, re-
cognizes that in certain respects the latter does not comply with all current
IS0 rules on the presentation and content of an International Standard.
Therefore, the relevant technical body, within ISOflC 67, will review
IS0 10407:1993 and reissue it, when practicable, in a form complying with
these rules.
This standard is not intended to obviate the need for sound engineering
judgement as to when and where this standard should be utilized and
users of this standard should be aware that additional or differing require-
ments may be needed to meet the needs for the particular service in-
tended.
Standards referenced herein may be replaced by other international or
national standards that can be shown to meet or exceed the requirements
of the referenced standards.
Appendix A forms an integral part of this standard.

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IS0 10407:1993(E)
INTERNATIONAL STANDARD 0 IS0
Petroleum and natural gas industries - Drilling and
production equipment - Drill stem design and
operating Ii
1 Scope
This International Standard lays down the properties of drill pipe and tool joints, drill collars, kellys, and establishes
principles for the design and use of drill stem and their components.
2 Requirements
Requirements are specified in:
“API Recommended Practice 7G (RP 7G), Fourteenth Edition, August 1, 1990 - Recommended Practice for
Drill Stem Design and Operating Limits”,
which is adopted as IS0 10407.
For the purposes of international standardization, however, modifications shall apply to specific clauses and para-
graphs of publication API RP 7G. These modifications are outlined below.
Throughout publication API RP 7G, the conversion of English units shall be made in accordance with IS0 31, in
particular for the quantities listed hereafter.
1 inch (in) = 25,4 mm (exactly)
LENGTH
= 304,8 mm or 0,3048 m (exactly)
1 foot (ft)
= 6894,757 Pa
1 pound-force per square inch (Ibf/in*)
NOTE 1 bar = lo5 Pa
STRENGTH OR STRESS 1 pound-force per square inch (Ibf/in*) = 6 894,757 Pa
= I,355818 J
IMPACT ENERGY 1 foot-pound force (ftlbf)
1 foot-pound force (ftlbf) = 1,355818 N-m
TORQUE
The following formula was used to convert degrees Fahrenheit (OFI to degrees
TEMPERATURE
Celsius (“C):
“C = 5/9 (“F - 32)
= 0,0283168 m3 or 28,3168 dm3
VOLUME 1 cubic foot
dm3
1 gal (US) = 0,003 7854 m3 or 3,7854
dm3
1 barrel (US) = 0,158987 m3 or 158,987
= 0,453 592 37 kg (exactly)
MASS 1 pound (lb)
LINEIC MASS 1 pound per foot (Ib/ft) = 1,488 163 9 kg/m

IS0 10407:1993(E)
.l pound-force (Ibf) = 4'448222 N
FORCE
FLOW RATE 1 barrel/day = 0,158 987 m3/day
1 cubic foot per minute (ft3/min) = 0,02831685 m3/min
or 40,776 192 m3/day
Page 7
Information given in the POLICY is relevant to the API publication only.
Page 76
Pipe manufacturer
The given list of pipe manufacturers may be used on a provisional basis. In the future, the symbols should be
registered under an international registration scheme to be established according to Annex N of the lSO/lEC Di-
rectives, part 2.
IS0 10407:1993(E)
Recommended Practice for
Drill Stem Design and
Operating Limits
API RECOMMENDED PRACTICE 7G (RP 7G)
FOURTEENTH EDITION, AUGUST I,1990
American Petroleum Institute
1220 L Street, Northwest
Washington, DC 20005
This page intentionally left blank

IS0 10407:1993(E)
Issued by
AMERICAN PETROLEUM INSTITUTE
Production Department
FOR INFORMATION CONCERNING TECHNICAL CONTENTS OF
THIS PUBLICATION CONTACT THE API PRODUCTION DEPARTMENT,
2535 ONE MAIN PLACE, DALLAS, TX 75202 - [phone].
SEE BACK SIDE FOR INFORMATION CONCERNING HOW TO OBTAIN
ADDITIONAL COPIES OF THIS PUBLICATION.
Users of this publication should become completely familiar with its scope
and content. This publication is intended to supplement rather than
replace individual engineering judgment.
OFFICIAL PUBLICATION
REG. U.S. PATENT OFFICE
Copyright @ 1990 American Petroleum Institute

IS0 10407:1993(E)
American Petroleum Institute
TABLE OF CONTENTS
Page
Policy. .
Foreword.~ .
..................................................... 4
Sectionl: Scope
..................... 5
Section 2: Properties of Drill Pipe and Tool Joints
New Drill Pipe Dimensional, Torsional, Tensile, Collapse,
....................................... 6
and Internal Pressure Data
Premium Class Drill Pipe Torsional, Tensile, Collapse,
...................................... 9
and Internal Pressure Data.
Class 2 Drill Pipe Torsional, Tensile, Collapse,
....................................... 11
and Internal Pressure Data
Mechanical Properties and Drift Diameters for New Tool
............................... 13
Joints and New Grade E Drill Pipe
Mechanical Properties and Drift Diameters for New Tool
.......................... 15
Joints and New High Strength Drill Pipe
Recommended Minimum OD and Make-Up Torque of
......................................... 18
Weld-on Type Tool Joints
Buoyancy Factors . 22
............................... 24
Tool Joint Torsional Strength Curves.
.................................. 33
Section 3: Properties of Drill Collars
................................................ 33
Drill Collar Weight
Recommended Make-Up Torque for Rotary Shouldered
.......................................... 34
Drill Collar Connections
....................... 37
Drill Collar Bending Strength Ratio Curves
........................................ 44
Section 4: Properties of Kellys
....................................... 47
Section 5: Design Calculations.
....................... 51
Section 6: Limitations Related to Hole Deviation
..................... 61
Section 7: Limitations Related to Floating Vessels
........... 61
Section 8: Drill Stem Corrosion and Sulfide Stress Cracking
......... i ........................ 65
Section 9: Special Service Problems
............................................. 65
Critical Rotary Speeds
................................................ 65
Fishing Techniques
....................................... 66
Biaxial Loading of Drill Pipe
Section 10: Identification, Inspection and Classification
of Drill Stem Components . 71
....................... 71
Drill Pipe and Tubing Work String Inspection
............................................... 71
Tool Joint Inspection
....................................... 76
Used Drill Pipe Classification
............................ 77
Used Tubing Work String Classification
...................... 78
Maximum Allowable Hook Load for Drill Pipe
........... 81
Maximum Allowable Hook Load for Tubing Work Strings
........................................ 84
Used Drill Collar Inspection
..................... 86
Section 11: Welding on Down Hole Drilling Tools.
............................ 87
Section 12: Dynamic Loading of Drill Pipe
......................... 87
Section 13: Classification of Rock (Roller) Bits
.......................... 90
Appendix A: Strength and Design Formulas
References .
Requests for permission to reproduce or translate all
NOTE: This edition supersedes the Thirteenth Edition
or any part of the material published herein should be
of this recommended practice dated April 1, 1989. It
addressed to th.e Director, Production Department, 2535
includes changes adopted at the 1989 Standardization
One Main Place, Dallas TX 75202.
Conference as reported in Circ PS-1887, and as subse-
quently approved by letter ballot.

IS0 10407:1993(E)
RP7G: Drill Stem Design and Operating Limits
POLICY
API PUBLICATIONS NECESSARILY ADDRESS THING CONTAINED IN THE PUBLICATION BE
PROBLEMS OF A GENERAL NATURE. WITH
CONSTRUED AS INSURING ANYONE AGAINST
RESPECT TO PARTICULAR CIRCUMSTANCES, LIABILITY FOR INFRINGEMENT OF LETTERS
LOCAL, STATE AND FEDERAL LAWS AND PATENT.
REGULATIONSSHOULDBEREVIEWED.
GENERALLY,APISTANDARDSAREREVIEWED
AND REVISED,REAFFIRMED,ORWITHDRAWN
API IS NOT UNDERTAKING TO MEET DUTIES
AT LEAST EVERY FIVE YEARS.SOMETIMES A
OF EMPLOYERS, MANUFACTURERS OR SUP-
ONE-TIME EXTENSION OF UPTO TWO YEARS
PLIERSTO WARN AND PROPERLYTRAIN AND
WILLBEADDEDTOTHISREVIEWCYCLE.THIS
EQUIP THEIR EMPLOYEES, AND OTHERS EX-
PUBLICATIONWILLNOLONGERBEINEFFECT
POSED, CONCERNING HEALTH AND SAFETY
FIVE YEARS AFTER ITS PUBLICATION DATE
RISKSANDPRECAUTIONSNORUNDERTAKING
ASANOPERATIVE APISTANDARDOR,WHERE
THEIROBLIGATIONSUNDERLOCAL,STATE,OR
AN EXTENSION HAS BEEN GRANTED, UPON
FEDERALLAWS.
REPUBLICATION. STATUS OF THE PUBLICA-
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METHOD,APPARATUS,ORPRODUCTCOVERED DATED QUARTERLY BY API, 1220 L ST., N.W.,
BYLE'IfTERSPATENT.NEITHERSHOULDANY- WASHINGTON,D.C.20005.

IS0 10407:1993(E)
American Petroleum Institute
RECOMMENDED PRACTICE FOR DRILL STEM DESIGN
AND OPERATING LIMITS
FOREWORD
American Petroleum Institute (API) Recommended
a. This recommended practice is under the jurisdic-
Practices are published to facilitate the broad availabil-
tion of the API Committee on Standardization of Drill-
ity of proven, sound engineering and operating prac-
ing and Servicing Equipment.
tices. These Recommended Practices are not intended to
obviate the need for applying sound judgment as to
b. The purpose of this recommended practice is to
when and where these Recommended Practices should
standardize techniques for the procedure of drill stem
be utilized.
design and to define the operating limits of the drill
stem.
The formulation and publication of API Recommended
Practices is not intended to, in any way, inhibit anyone
c. References are listed at the end of this publication.
from using any other practices.
Any Recommended Practice may be used by anyone
desiring to do so, and diligent effort has been made by
API to assure the accuracy and reliability of the data
Attention Users of this Publication: Portions of this
contained herein. However, the Institute makes no
publication have been changed from the previous edi-
representation, warranty, or guarantee in connection
tion. The location of changes has been marked with a
bar in the margin. In some cases the changes are signif- with the publication of any Recommended Practice and
icant, while in other cases the changes reflect minor hereby expressly disclaims any liability or responsibil-
editorial adjustments. The bar notatiqns in the margins ity for loss or damage resulting from their use, for any
are provided as an aid to users to identify those parts of violation of any federal, state, or municipal regulation
this publication that have been changed from the pre- with which an API recommendation may conflict, or for
vious edition, but API makes no warranty as to the the infringement of any patent resulting from the use of
accuracy of such bar notations. this publication.
SECTION 1
SCOPE
1.1 Coverage. This recommended practice involves related to operating limitations which may reduce the
not only the selection of drill string members, but also normal capability of the drill string. Section 10 con-
the considerations of hole angle control, drilling fluids, tains classification system for used drill pipe and used
weight and rotary speed, and other operational tubing work strings, and identification and inspection
procedures. procedures for other drill string members. Section 11
contains statements regarding welding on down hole
1.2 Sections 2, 3, 4, and 5 provide a step-by-step
tools. Section 13 covers the classification system for
procedure for selection of drill string members in nor-
rock (roller) bits.
mal, near-vertical holes. Sections 6, 7, 8, 9, and 12 are
IS0 10407:1993(E)
RP7G: Drill Stem Design and Operating Limits 5
SECTION 2
PROPERTIES OF DRILL PIPE AND TOOL JOINTS
2.1 This section contains a series of tables designed
cal torsional strength, assuming all other factors are
to present the dimensional, mechanical, and er-
constant.
formance pro erties of new and used drill pipe. Ta B les
are also inc P uded listing these roperties for tool 2.7 The greatest reduction in theoretical torsional
joints used with new and used B r-ill pi e. Separate strength of a tool joint during its service life occurs
tables are included for Torsional and f ensile Data with OD wear. At whatever point the tool joint box
area becomes the smaller or controlling area, any
and for Collapse and Internal Pressure Data.
further reduction in OD causes a direct reduction in
2.2 All drill pipe and tool joint properties tables are
torsional strength. If the box area controls when the
included in Section 2.
initial OD wear reduces torsional
tool joint is new,
strength. If the pin controls when new, some OD wear
2.3 Values listed in drill pipe tables are based on
may occur before the torsional strength is affected.
accepted standards of the industry and calculated
Conversely, it is possible to increase torsional strength
from formulas in Appendix A.
by making joints with oversize OD and reduced ID.
2.8 Minimum OD, box shoulder, and make-up torque
Tool Joint Drift Diameters
values listed in Table 2.12 were determined using the
following criteria:
2.4 Recommended drift diameters for new drill string
a. Calculations for recommended tool joint makeup
assemblies are shown in column 8 of Tables 2.10 and 2.11.
torque are based on the use of a thread com-
Drift bars must be a minimum of four inches long. The
pound containing 40-60% by weight of finely
drift bar must pass through the upset area but need not
powdered metallic zinc applied to all threads and
penetrate more than twelve inches beyond the base of the
elevator shoulder. shoulders, and containing not more than 0.3%
total active sulfur. Calculations are also based on
a tensile stress of 50% of the minimum tensile
Torsional Strength of Tool Joints
yield for new joints and 60% for used joints.
2.5 The torsional strength of a tool joint is a func-
b. In calculation of torsional strengths of tool joints,
tion of several variables. These include the strength
both new and worn, the bevels of the tool joint
of the steel, connection size, thread form, lead, taper,
shoulders are disregarded.
and coefficient of friction on mating surfaces, threads,
C. Premium Class Drill String is based on drill pipe
or shoulders. The torque required to yield a rotary
shouldered connection may be obtained from the
having a minimum wall thickness of 80%.
equation in Par. A.8, Appendix A.
d. Class 2 drill string allows drill pipe with a min-
imum wall thickness of 70%.
2.6 The pin or box area, whichever controls, is the
e. The tool joint to pipe torsional ratios that are
largest factor and is subject to the widest variation.
used here (20.80) are recommendations only and
The tool joint outside diameter (OD) and inside diame-
it should be realized that other combinations of
ter (ID) large1 determine the strength of the joint in
dimensions may be used. A given assembly that
torsion. The d D affects the box area and the ID af-
fects the pin area. Choice of OD and ID determines the is suitable for certain service may be inadequate
areas of the pin and box and establishes the theoreti-
for some areas and overdesigned for others.

IS0 10407:1993(E)
American Petroleum Institute
TABLE 2.1
NEW DRILL PIPE DIMENSIONAL DATA
1 4
2 3 5 6 7
Section
Nominal Area Polar
Size
Weight Plain Body of Sectional
OD Threads &
End Wall ID Pipe2 Modulus3
in. in.
Couplings Weight’ Thickness sq. in. cu. in.
d
D
Ib/ft Ib/ft in. A Z
2% 4.85 4.43 A90 1.995 1.3042 1.321
6.65 6.26 .280 1.8429 1.733
1.815
2%
6.85 6.16 .217 2.441 1.8120 2.241
10.40 9.72 .362 2.151
2.8579 3.204
3%
9.50 8.81 .254 2.5902 3.923
2.992
13.30 12.31 .368 3.6209 5.144
2.764
15.50 14.63 .449 2.602 4.3037 5.847
11.85 10.46 .262 3.476 3.0767 5.400
14.00 12.93 .330 3.340 3.8048 6.458
15.70 14.69 .380 3.240 4.3216 7.157
4% .271
13.75 12.24 3.958 3.6004 7.184
16.60 14.98 .337 3.826 4.4074 8.543
20.00 18.69 .430 10.232
3.640 5.4981
22.82 21.36 .500 3.500 6.2832 11.345
5 16.25 14.87 .296 4.408 4.3743 9.718
17.93 .362 4.276 5.2746 11.415
19.50
14.491
25.60 24.03 .500 4.000 7.0686
19.20
5% 16.87 .304 4.892 4.9624 12.221
21.90 19.81 .361 4.778 5.8282 14.062
24.70 22.54 .415 4.670 6.6296 15.688
22.19 .330 5.965 6.5262 19.572
6% 25.20
‘Ib/ft = 3.3996 x A (col. 6)
2A = 0.7854 (D* - d’)
3Z = 0.19635 4
(,‘Dd >
IS0 10407:1993(E)
RP7G: Drill Stem Design and Operating Limits 7
TABLE 2.2
NEW DRILL PIPE TORSIONAL
AND TENSILE DATA
1 2 3 4 5 6 7 8 9 10
Nom.
Weight
Torsional Data*
Tensile Data Based on Minimum Values”
Size Thds &
Torsional Yield Strength, ft-lb
Load at the Minimum Yield Strength, lb;
A
00 Couplings y \ \
/
In. lb.
E 95 105 135 E 105 135
23%3 4.85 4763. 6033.
6668. 8574. 97817. 123902. 136944. 176071.
6250. 7917. 8751. 248786.
6.65 11251. 138214. 175072. 193500.
2% 6.85 8083. 10238. 11316. 244624.
14549. 135902. 172143. 190263.
11554. 14635.
10.40 16176. 20798. 214344. 271503. 300082. 385820.
3% 14146. 17918.
9.50 19805. 25463. 194264. 246068. 271970. 349676.
13.30 18551. 23498.
25972. 33392. 271569. 343988. 380197. 488825.
15.50 21086. 26708. 29520. 37954. 322775. 408848. 451685. 580995.
4 11.85 19474. 24668. 27264. 35054. 230755. 292290. 323057. 415360.
29498.
14.00 23288. 32603. 41918. 285359. 361454. 399502. 513646.
15.70 25810. 32692. 36134. 46458. 324118. 410550. 453765. 583413.
4% 13.75 25907. 32816. 36270. 46633. 270034. 342043. 378047. 486061.
16.60 30807. 39022. 43130. 55453. 330558. 418707. 462781. 595004.
20.00 36901. 46741. 51661. 66421. 412358. 522320. 577301. 742244.
22.82 40912. 51821. 57276. 73641. 471239. 596903. 659735. 948230.
5 16.25 35044. 44389. 49062. 63079. 328073. 415559. 459302. 590531.
19.50 41167. 52144. 57633. 74100. 395595. 501087. 553833. 712070.
25.60 52257. 66192. 73159. 671515. 742201. 954259.
94062. 530144.
19.20 44074. 55826. 61703. 471429. 521053. 669925.
79332. 372181.
50710. 64233. 611963. 786809.
21.90 70994. 91278. 437116. 553681.
24.70 56574. 71660. 629814. 696111. 894999.
79204. 101833. 497222.
6% 70580. 89402. 685250. 881035.
25.20 98812. 127044. 489464. 619988.
*Based on the shear strength equal to 57.7% of minimum yield strength and nominal wall thickness.
Minimum torsional yield strength calculated from Formula AX, Par. A.9, Appendix A.
**Minimum tensile strength calculated from Formula A.13, Par. A.7, Appendix A.
IS0 10407:1993(E)
American Petroleum Institute
TABLE 2.3
NEW DRILL PIPE COLLAPSE AND INTERNAL PRESSURE DATA
Collapse Pressure Based On
Size Nom. Intcrnul Prcssuw Al
Minimum Values, psi. Minimum Yield Strc-ngth. psi.
OD Weight
Thds& f
Couplings E 95 ’ E 95 106 135’
in. lb.
13984. 15456. 14700. 18900.
2% 4.85 11040. 19035. 10500. 13300.
6.65 15599. 19759. 21839. 28079. 15474. 19600. 21663. 27853.
2% 6.85 10467. 12940. 14020. 17034. 9907. 12548. 13869. 17832.
10.40 16509. 20911. 23112. 29716. 16526. 20933. 23137. 29747.
3% 10001. 12077. 13055. 15748. 9525. i2065. 13335. 17145.
9.50
14113. 17877. 19758. 25404. 13800. 17480. 19320. 24840.
13.30
15.50 16774. 21247. 23484. 30194. 16838. 21328. 23573. 30308.
4 9978. 10708. 12618. 12036. 15474.
11.85 8381. 8597. 10889.
14382. 15896. 20141. 10828. 13716. 15159. 19491.
14.00 11354.
16335. 18055. 23213. 12469. 15794. 17456. 22444.
15.70 12896.
4% 8412. 8956.
13.75 7173. 10283. 7904. 10012. 11066. 14228.
12765. 13825. 16773. 13761.
16.60 10392. 9829. 12450. 17693.
16421. 18149. 17558.
20.00 12964. 23335. 12542. 15886. 22575.
22.82 14815. 18765. 20741. 26667. 14583. 18472. 20417. 26250.
5 16.25 6938. 8108. 8616. 9831. 7770. 9842. 10878. 13986.
19.50 9962. 12026. 12999. 15672. 9503. 12037. 13304. 17105.
25.60 13500. 17100. 18900. 24300. 13125. 16625. 18375. 23625.
5% 19.20 6039. 6942. 7313. 8093. 7255. 9189. 10156. 13058.
21.90 8413. 10019. 10753. 12679. 8615. 10912. 12061. 15507.
24.70 10464. 12933. 14013. 17023. 9903. 12544. 13865. 17826.
6% 4788. 5321. 5500. 6036. 6538. 8281. 9153. 11768.
25.20
NOTE: Calculations are based on formulas in API Bul 5C3.
1.2
IS0 10407:1993(E)
RP7G: Drill Stem Design and Operating Limits
TABLE 2.4
USED DRILL PIPE
TORSIONAL AND TENSILE DATA
API PREMIUM CLASS
1 2 3 4 5 6 7 8 9 10
New Wt. 1~2Torsional Yield Strength Based On
*Tensile Data Based On Uniform Wear
Nom. W/ Uniform Wear, ft-lb Load At Minimum Yield Strength, lb,
-
Size Thds &
L
L
N
3 f
OD Couplings ’
in. Ib/ft E 95 105 135 E 105 135
3725. 4719. 5215. 97398. 107650. 138407.
2% 4.85 6705. 76893.
6093. 6735. 193709.
6.65 4811. 8659. 107616. 136313. 150662.
8020. 8865. 149725.
2% 6.85 6332. 11397. 106946. 135465. 192503.
8858. 11220. 12401. 233149. 299764.
10.40 15945. 166535. 210945.
14052. 15531. 214171.
3% 9.50 11094. 19968. 152979. 193774. 275363.
14361. 18191. 20106. 297010. 381870.
13.30 25850. 212150. 268723.
16146. 20452. 22605. 250620. 317452. 350868. 451115.
15.50 29063.
19392. 21433. 327630.
4 11.85 15310. 27557. 182016. 230554. 254823.
23048. 25474. 224182. 313854. 403527.
14.00 18196. 32752. 283963.
25418. 28094. 253851. 321544. 355391. 456931.
15.70 20067. 36120.
25844. 28564.
4% 13.75 20403. 36725. 213258. 270127. 298561. 383864.
30576. 33795. 260165. 329542. 364231. 468297.
16.60 24139. 43450.
28683. 36332. 40157. 322916. 409026. 452082. 581248.
20.00 51630.
40010. 44222. 514593. 661620.
22.82 31587. 56856. 367566. 465584.
34969. 38650. 259155. 328263. 362817. 466479.
5 16.25 27607. 49693.
32285. 40895. 45199. 311535. 394612. 436150. 560764.
19.50 58113.
51356. 56762. 580566. 746443.
25.60 40544. 72979. 414690. 525274.
34764. 44035. 48670. 294260. 372730. 411965. 529669.
5% 19.20 62575.
39863. 50494. 55809. 344780. 436721. 482692. 620604.
21.90 71754.
56139. 62048. 547799. 704313.
24.70 44320. 79776. 391285. 495627.
70637. 78072. 387466. 490790. 542452. 697438.
6% 25.20 55766. 100379.
‘Based on the shear strength equal to 57.7% of minimum yield strength.
2Torsional data based on 20% uniform wear on outside diameter and tensile data based on 20% uniform wear on outside
diameter.
IS0 10407:1993(E)
American Petroleum Institute
TABLE 2.5
USED DRILL PIPE COLLAPSE AND INTERNAL PRESSURE DATA
API PREMIUM CLASS
1 3
2 4 5 6 7 8 9 10
Nominal
Collapse Pressure Based On 'Minimum internal Yield Pressure At
OD
Weight
Minimum Values, psi, Minimum Yield Strength, psi
Size Thds.&
\ T
Couplings *
in.
E 95
Ib/ft 95 105 135 E 105 135
13440.
4.85 8522. 10161. 10912. 12891. 9600. 12160. 17280.
6.65 13378. 16945. 18729. 24080. 14147. 17920. 19806. 25465.
6.85 7640. 9017. 9633. 11186. 9057. 11473. 12680. 16303.
10.40 14223. 18016. 19912. 25602. 15110. 19139. 21153. 27197.
9.50 7074. 8284. 8813. 10093. 8709. 11031. 12192. 15675.
13.30 12015. 15218. 16820. 21626. 12617. 15982. 17664. 22711.
15.50 14472. 18331. 20260. 26049. 15394. 19499. 21552. 27710.
4 11.85 5704. 6508. 6827. 7445. 7860. 9956. 11004. 14148.
14.00 9012. 10795. 11622. 13836. 9900. 12540. 13860. 17820.
15.70 10914. 13825. 15190. 18593. 11400. 14440. 15960. 20520.
4'/? 13.75 4686. 5190. 5352. 5908. 7227. 9154. 10117. 13008.
16.60 7525. 8868. 9467. 10964. 8987. 11383. 12581. 16176.
20.00 10975. 13901. 15350. 18806. 11467. 14524. 16053. 20640.
22.82 12655. 16030. 17718. 22780. 13333. 16889. 18667. 24000.
5 16.25 4490. 4935. 5067. 5661. 7104. 8998. 9946. 12787.
19.50 7041. 8241. 8765. 10029. 8688. 11005. 12163. 15638.
25.60 11458. 14514. 16042. 20510. 12000. 15200. 16800. 21600.
5% 19.20 3736. 4130. 4336. 4714. 6633. 8401. 9286. 11939.
21.90 5730. 6542. 6865. 7496. 7876. 9977. 11027. 14177.
24.70 7635. 9011. 9626. 11177. 9055. 11469. 12676. 16298.
6% 25.20 2931. 3252. 3353. 3429. 5977. 7571. 8368. 10759.
---___---_
‘Data are based on minimum wall of 809’0 nominal wall. Collapse pressures are based on uniform OD wear. Internal pressures are based
on uniform wear and nominal OD.
NOTE. Calculations for Premium Class drill pipe are based on formulas in API Bul 5C3.
IS0 1om7:1993(E)
RP’7G: Drill Stem Design and Operating Limits
TABLE 2.6
USED DRILL PIPE TORSIONAL AND TENSILE DATA
API CLASS 2
1 2 3 4 5 6 7 8 9 10
New Wt. l12Torsional Yield Strength Based On *Tensile Data Based on Uniform Wear
Nom.W/
Uniform Wear,ft-lb Load At Minimum Yield Strength, lb,
A *
Size Thds. & r \
3 r
OD Couplings
in. Ib/ft E 95 105 135 E 95 105 135
2% 4.85 3224. 4083. 4513.
5802. 66686. 84469. 93360. 120035.
6.65 4130. 5232.
5782. 7434. 92871. 117636. 130019. 167167.
2% 6.85 5484. 6946.
7677. 9871. 92801. 117549. 129922. 167043.
10.40 7591. 9615. 181839.
10627. 13663. 143557. 200980. 258403.
3% 9612. 12176.
9.50 13457. 17302. 132793. 168204. 185910. 239027.
12365. 15663.
13.30 17312. 22258. 183398. 232304. 256757. 330116.
15.50 13828. 17515.
19359. 24890. 215967. 273558. 302354. 388741.
11.85 13281. 16823. 18594. 23907. 158132. 200301. 221385. 284638.
14.00 15738. 19935. 22034. 28329. 194363. 246193. 272108. 349852.
15.70 17315. 21932.
24241. 31166. 219738. 278335. 307633. 395528.
13.75 17715. 22439. 24801. 31887. 185389. 234827. 259545.
333701.
16.60 20908. 26483. 29271. 37634. 225771. 285977. 316080. 406388.
20.00 24747. 31346. 34645. 44544. 279502. 354035. 391302. 503103.
22.82 27161. 34404. 38026. 48890. 317497. 402163. 444496. 571495.
5 16.25 23974. 30368. 33564. 43154. 225316. 285400. 315442. 405568.
19.50 27976. 35436. 39166. 50356. 270432. 342548. 378605. 486778.
25.60 34947. 44267. 48926. 502223. 645715.
62905. 358731. 454392.
5% 19.20 30208. 38263. 42291. 460717.
54374. 255954. 324208. 358335.
21.90 34582. 43804. 48414. 419346. 539160.
62247. 299533. 379409.
24.70 38383. 48619. 53737.
69090. 339533. 430076. 475347. 611160.
6% 25.20 48497. 61430. 67896.
87295. 337236. 427166. 472131. 607026.
‘Based on the shear strength equal to 57.7% of minimum yield strength.
2Torsionai data based on 30% uniform wear on outside diameter and tensile data based on 30% uniform wear on outside diameter.
IS0 10407:1993(E)
American Petroleum Institute
TABLE 2.7
USED DRILL PIPE COLLAPSE AND INTERNAL PRESSURE DATA
API CLASS 2
1 3 4 5 6 7 8 9 1Q
Collapse Pressure Based On 'Minimum Internal Yield Pressure At
Nominal
Minimum Values, psi. Minimum Yield Strength, psi.
Weight
L L
Size Thds & I
b I 3
OD Couplings
in. E 95 105 135 E 95 105 135
Ib/ft
2% 4.85 6852. 7996. 8491. 9664. 8400. 10640. 11760. 15120.
6.65 12138. 15375. 16993. 21849. 12379. 15680. 17331. 22282.
2% 6.85 6055. 6963. 7335. 8123. 7925. 10039. 11095. 14265.
12938. 16388. 18113. 23288. 13221. 16746. 18509. 23798.
10.40
5544. 6301. 6596. 7137. 9652. 10668. 13716.
3% 9.50 7620.
13753. 15042. 18396. 15456. 19872.
13.30 10858. 11040. 13984.
16686. 18443. 23712. 18858. 24246.
15.50 13174. 13470. 17062.
4702. 4876. 5436. 12380.
4 11.85 4311. 6878. 8712. 9629.
14.00 7295. 8570. 9134. 10520. 8663. 10973. 12128. 15593.
15.70 9531. 11468. 12374. 14840. 9975. 12635. 13965. 17955.
4287.
4% 13.75 3397. 3845. 4016. 6323. 8010. 8853. 11382.
16.60 5951. 6828. 7185. 7923. 7863. 9960. 11009. 14154.
20.00 9631. 11598. 12520. 15033. 10033. 12709. 14047. 18060.
22.82 11458. 14514. 16042. 20510. 11667. 14779. 16333. 21000.
5 16.25 3275. 3696. 3850. 4065. 6216. 7874. 8702. 11189.
19.50 5514. 6262. 6552. 7079. 9629. 10643. 13684.
7602.
25.60 10338. 12640. 13685. 16587. 13300. 14700. 18900.
10500.
5% 19.20 2835. 3128. 3215. 3265. 5804. 7351. 8125. 10447.
21.90 4334. -4733. 4899. 5465. 12405.
6892. 8730. 9649.
24.70 6050. 6957. 7329. 8115. 11092. 14261.
7923. 10035.
6% 25.20 2227. 2343. 2346. 2346. 7322. 9414.
5230. 6625.
'Data are based on minimum wall of 70% nominal wall. Collapse pressures are based on uniform CD wear.
Internal pressures are based on uniform wear and nominal OD.
NOTE:CalculationsforClass 2 drill pipe are based on formulas in API Bul5C3.
EDITORIAL NOTE:Tables 2.8 and 2.9were deleted in 12th edition of RP 7G and the remaining Tables werenot
renumbered.
IS0 10407:1993(E)
RP7G: Drill Stem Design and Operating Limits 13
TABLE 2.10
MECHANICAL PROPERTIES OF NEW TOOL JOINTS
AND NEW GRADE E DRILL PIPE
1 2 3 8 11 12
4 5 6 7 9 10
Drill Pipe Data Tool Joint Data Mechanical Properties
Drift
A A A
\ / 3
‘Nom Nom. Approx. ’ Diam- ’
Tensile Yield, lb Torsional Yld, ft-lb
Size Wt. Wt.* OD ID eter”
Type --
‘Pipe 3Tool Joint
in. Ib/ft Conn. in. in. in. *Pipe Tool Joint’
I b/ft Upset
2% 4.85 5.16 EU NC26(IF) 3% 1% 1.625 97817. 313681. 4763. 6478.b
4.89 EU OH 3% 2 1.807 97817. 206416. 4763. 4525.~
4.97 EU SLHSO 3% 2 1.850 97817. 202670. 4763. 5127-p
5.06 EU wo 3% 2 1.807 97817. 205369. 4763. 4533.p
6250. 6478.b
6.65 6.92 EU NC26(IF) 3% 1% 1.625 138214. 313681.
6.83 EU OH 3% 1% 1.625 138214. 294774. 6250. 6298.b
6.71 IU PAC 2% 1% 1.250 138214. 238634. 6250. 4690.P
5127.~
6.73 EU SLHSO 3% 2 1.670 138214. 202670. 6250.
2% 6.85 7.36 EU NC31(IF) 4% 2% 2.000 135902. 447130. 8083. 11869-p
6.85 EU OH 3%’ 2.253 135902. 223937. 8083. 5589.P
2’4 6
6.96 EU SLHSO 3% 2.296 135902. 260783. 8083. 7630.~
2’4 6
8083. 7511.p
7.19 EU wo 4% 2.253 135902. 289264.
27/16
10.40 10.76 EU NC31(IF) 4% 2% 1.963 214344. 447130. 11554. 11869.~
11554. 8818.P
10.51 EU OH 3% 1.963 214344. 345705.
25i32
1.375 11554. 5735.P
10.15 IU PAC 3% 1 ‘/2 214344. 273164.
10.51 EU SLHSO 3% 2.006 214344. 382551. 11554. 11294.~
z5/32
1.750 11554.
10.99 IU XH 4% 1% 214344. 516757. 13595.p
1.625 11554. 6478.B
10.28 IU NC26(SH) 3% 1% 214344. 313681.
14146. 18107.~
3% 9.50 10.44 EU NC38(IF) 4% 2”/ 2.563 194264. 587308.
14146. 11867.~
9.89 EU OH 4% 3 2.804 194264. 392295.
14146. 12646.~
10.05 EU SLHSO 4% 3 2.847 194264. 366445.
14146. 13333.~
10.20 EU wo 4% 3 2.804 194264. 434198.
2.619 18551. 23847.~
13.30 14.41 EU H90 5% 2% 271569. 663633.
2.457 18551. 18107.~
13.77 EU NC38(IF) 4% 2”/ 271569. 587308.
18551. 17305.~
13.77 EU OH 4% 2”/,6 2.414 271569. 559806.
18551. 11869.P
13.40 IU NC31(SH) 4% 2% 2.000 271569. 447130.
2.313 18551. 17493.~
13.94 EU XH 4% 271569. 584542.
2’4 6
21086. 20326.~
15.50 16.39 EU NC38(IF) 5 2.414 322775. 649158.
2'46
19474. 35441.p
4 11.85 13.07 IU H90 5’h 2’3/16 2.688 230755. 914246.
19474. 33625.~
13.51 EU NC46(IF) 6 3% 3.125 230755. 901164.
12.10 EU OH 5’/4 3’ 5/32 3.287 230755. 621623. 19474. 21967.b
19474. 29469.~
12.91 EU wo 5% 3.313 230755. 800590.
3’/16
‘The tensile yield strength of Grade E drill pipe is based on 75,000 psi minimum yield strength.
*The torsional yield strength is based on a shear strength of 57.7Or6 of the minimum yield strength.
3The tensile strength of the tool joint pin is based on 120,000 psi minimum yield and the cross sectional area at
the root of the thread V8 inch from the shoulder.
*Tool Joint plus drill pipe, for Range 2 steel pipe (See Appendix A for method of calculation).
**See Par. 2.4.
f: p=pin limited yield. b=box limited yield. P or B indicates that tool joint could not meet 80% oftubetorsion yield.
IS0 10407:1993(E)
American Petroleum Institute
______- --__- --. P.-v---
---
TABLE 2.10 (continued)
MECHANICAL PROPERTIES OF NEW TOOL JOINTS
AND NEW GRADE E DRILL PIPE
4 5 6 7 8 9
1 2 3 10 11 12
Drill Pipe Data Tool Joint Data Mechanical Properties
Drift
% A A
I \ / \ 1
Approx. Diam-
Nom.
Nom. Tensile Yield, lb , Torsional Yld, ft-lb
OD eter”
Type ID A,
Size Wt. Wt.’
Upset Conn. in.
in. Ib/ft. in. in. ‘Pipe 3Tool Joint 2Pipe Tool Joint’
Ib/ft
14.00 15.06 IU NC40( FH) 5% 213/,6 2.688 285359. 711611. 23288. 23487-p
15.41 IU H90 5% 213/,6 2.688 285359. 914246. 23288. 35441.p
15.85 EU NC46(IF) 6 3% 3.125 285359. 901164. 23288. 33625.~
15.03 EU OH 5% 3% 3.125 285359. 760142. 23288. 27279.~
14.37 IU SH 4% 285359. 525637. 23288. 15581.P
2.438
2g/,6
16.81 IU NC40(FH) 5% 2"/ 2.563 324118. 776406. 25810. 25673.~
15.70
15.70 17.07 IU H90 5% 213,;; 2.688 324118. 914246. 25810. 35441.p
15.70 17.51 EU NC46(IF) 6 3% 3.095 324118. 901164. 25810. 33625.~
4% 13.75 15.21 IU H90 6 3% 3.125 270034. 938984. 25907. 39021-p
14.93 EU NCSO(IF) 6% 3% 3.625 270034. 25907. 37676.~
939095.
14.06 EU OH 5% z3’ix2 3.770 270034. 555131. 25907. 20965.p
14.79 EU wo 6% 3% 3.750 270034. 868775. 25907. 34440.p
16.60 18.14 IEU FH 6 3 2.875 330558. 30807. 34780.~
976156.
IEU
17.81 H90 6 3% 3.125 330558. 30807. 39021 .p
938984.
17.98 EU NCSO(IF) 6% 3%' 3.625 330558. 939095. 30807. 37676.~
17.10 EU OH 5% 3% 3.625 30807. 27272.~
330558. 714267.
16.79 IEU NC38(SH) 5 2"/ 2.563 330558. 30807. 18346.P
587308.
18.37 IEU NC46(XH) 6% 3% 3.125 330558. 30807. 33993.p
901164.
20.00 21.63 IEU FH 6 3 412358. 36901. 34780.~
2.875 976156.
21.63 IEU H90 6 3 2.875 412358. 36901. 45258-p
1086246.
21.62 EU NCSO(IF) 6% 3% 3.452 412358. 1025980. 36901. 41235.~
22.09 IEU NC46(XH) 6% 3 36901. 39659.~
2.875 412358. 1048426.
22.82 24.07 EU NCSO(IF) 6% 3% 471239. 1025980. 40912.
3.452
IEU NC46(XH) 6% 3 40912.
24.59 2.875 471239. 1048426.
5 19.50 IEU 5%FH 7 3% 1448407. 41167. 61352.b
22.26 3.625 395595.
20.89 IEU NCSO(XH) 6% 3% 3.625 395595. 41167. 37676.~
939095.
IEU 5’/2FH 7 3% 3.375 530144. 1619231. 52257. 61352.b
25.60 28.26
IEU NC50( XH) 6% 3% 1109920. 52257. 44673.~
26.89 3.375 530144.
5% 21.90 23.77 IEU FH 7 4 3.875 437116. 1265802. 50710. 55933.p
IEU FH 7 4 56574. 55933.p
24.70 26.33 3.875 497222. 1265802.
25.20 27.3 IEU FH 8 5 4.875 489479. 1448800. 70580. 74200.~
6%
‘The tensile yield strength of Grade E drill pipe is based on 75,000 psi minimum yield strength.
2The torsional yield strength is based on a shear strength of 57.7% of the minimum yield strength.
3The tensile strength of the tool joint pin is based on 120,000 psi yield and the cross sectional area at the root of
the thread V8 inch from the shoulder.
*Tool Joint plus drill pipe, for Range 2 steel pipe (See Appendix A for method of calculation).
**See Par. 2.4.
f: p=pin limited yield. b=box limited yield. P or B indicates that tool joint could not meet 80% of tube torsion yield.
IS0 10407:1993(E)
RP 7cI: Drill Stem Design and Operating Limits 15
TABLE 2.11
MECHANICAL PROPERTIES OF NEW TOOL JOINTS
AND NEW HIGH STRENGTH DRILL PIPE
2 3 4 5 6 7 11 12
1 8 9 10
Drill Pipe Data Mechanical Properties
Tool Joint Data
\ I
A
. , Drift r .
, \
Approx. Type Upset
Nom. Nom. -Tensile Yield, lb Torsional Yld., ft-lb
Diam-
Fm
and 00
Size Wt. Wt.’ ID eter”
Pipe *Tool Joint ‘Pipe Tool Joint’
I b/ft Pipe Grade Conn. in. in. in.
in. Ib/ft
EU-X 6478. b
2% 6.65 7.01 NC26(IF 3% 1% 1.625 175072. 313681. 7917.
6.89 EU-X SLHSO 3% 1 ‘V,e 1.670 175072. 270043. 7917. 6884. p
6.65 7.01 EU-G NC26(IF 3% 1% 1.625 193500. 313681. 8751. 6478.0
6.89 EU-G SLHSO 3% 1 ’ 3/, fj 1.670 193500. 270043. 8751. 6884. P
2% 10.40 10.96 EU-X NC31 (IF 4% 2 1.875 271503. 495726. 14635. 13195.p
10.84 EU-X SLHSO 4 2 1.875 271503. 443756. 14635. 13226.~
10.40 10.96 EU-G NC31 (IF) 4% 2 1.875 300082. 495726. 16176. 13195-p
10.84 EU-G SLHSO 4 2 1.875 300082. 443756. 16176. 13226. p
10.40 11.38 EU-S NC31 (IF) 4% 1% 1.500 385820. 623844. 20798. 16944. p
11.12 EU-S SLHSO 4% 1% 1.500 385820. 571874. 20798. 17226. p
3% 13.30 14.63 EU-X H90 5% 2% 2.619 343988. 663633. 23498. 23847.~
14.41 EU-X NC38(IF 5 2.438 343988. 649158. 23498. 20326.~
1 2g4 6
14.07 EU-X SLHSO 4% 2.438 343988. 595806. 23498. 20879.p
2’4 6
13.30 14.49 EU-G NC38(IF 2.313 380197. 708063. 25972. 22213.~
) 27/1 6
14.07 EU-G SLHSO 4% 2.438 380197. 595806. 25972. 20879. p
2g4 6
13.30 33392. 26022. B
14.69 EU-S NC38(IF 5 2% 2.000 488825. 842440.
I
28078.~
14.69 EU-S SLHSO 5 2% 2.000 488825. 789087. 33392.
33392. 29930-p
15.04 EU-S NC40(4FH) 5% 2.313 488825. 897161.
z74 6
26708. 22213-p
15.50 16.69 EU-X NC38(IF) 5 2.313 408848. 708063.
27/1 6
29520.
15.50 16.88 EU-G NC38(IF) 5 2% 2.000 451885. 842440. 26022. b
29520. 27760.~
16.96 EU-G NC40(4FH) 5% 2.438 451885. 838257.
2’46
37954. 32943-p
15.50 17.56 EU-S NC40(4FH) 5% 2% 2.125 580995. 979996.
4 14.00 NJ-X NC40(FH) 5% 2’ v16 2.563 361454. 776406. 29498. 25673. p
15.30
u-x H90 5% 2.688 361454. 914246. 29498. 35441. p
15.55 2i3/16
EU-X NC46(IF) 3% 3.125 361454. 901164. 29498. 33625. p
16.14 6
399502. 897161. 32603. 30114-p
14.00 15.90 W-G NC40(FH) 5% 2.313
27/1 6
32603. 35441 .p
15.55 I&G H90 5% 2’3/16 2.688 399502. 914246.
32603. 33625.~
16.14 EU-G NC46(IF) 6 3% 3.125 399502. 901164.
41918. 36363.~
14.00 16.18 IU-s NC40( FH) 5% 2 1.875 513646. 1080135.
41918. 35441 .p
15.55 IU-s H90 5% 2’3/16 2.688 513646. 914246.
41918. 39229. p
16.38 EU-S NC46(lF) 6 2.875 513646. 1048426.
‘The torsional yield strength is based on a shear strength of 57.7% of the minimum yield strength.
*The tensile strength of the tool joint pin is based on 120,000 psi yield and the cross sectional area at the root of the
thread s/s inch from the shoulder.
*Tool Joint plus drill pipe, for Range 2 steel pipe (See Appendix A for method of calculation).
“See Par. 2.4.
f: p=pin limited yield. b=box limited yield. P or B indicates that tool joint could not meet 80% of tube torsion yield.
IS0 10407:1993(E)
American Petroleum Institute
TABLE 2.11 (continued)
MECHANICAL PROPERTIES OF NEW TOOL JOINTS
AND NEW HIGH STRENGTH DRILL PIPE
11 12
5 6 7 10
1 3 4 8 9
Mechanical Properties
Drill Pipe Data Tool Joint Data
\
L Drift (
. / \
/ \
Approx. Type Upset Diam- Tensile Yield, lb Torsional Yld., ft-lb
Nom. Nom.
Fm
eter”
and 00 ID
Sire Wt. Wt.’
Pipe *Tool Joint ‘Pipe Tool Joint’
Conn. in. in. in.
Ib/ft Pipe Grade
in. Ib/ft
NC40( FH) 5% 32692. 30114.p
4 15.70 17.55 IU-x 27/1 6 2.313 410550. 897161.
H90 5% 2i3/16 32692. 35441 .p
17.17 IU-x 2.688 410550. 914246.
NC46(IF) 6 3% 32692. 33625. p
17.75 EU-X 3.125 410550. 901164.
5%
15.70 17.55 IU-G NC40( FH) 27/1 6 2.313 453765. 897161. 36134. 30114.p
5% 2 ’ 3/, 6
17.17 IU-G H90 2.688 453765. 914246. 36134. 35441 .p
6 3%
17.75 EU-G NC46(IF) 3.125 453765. 901164. 36134. 33625.~
EU-S NC46(IF) 3 2.875 583413. 1048426. 46458. 39229. p
15.70 18.03
I EU-X FH 3 418707. 976156. 39022. 34780. p
4% 16.60 18.62 2.875
IEU-X H90 6 3% 3.125 418707. 938984. 39022. 39021 .p
18.39
NCSO(IF) 6% 3% 39022. 37676. p
18.34 EU-X 3.625 418707. 939095.
6%
NC46(XH) 3 39022. 39659.p
18.88 IEU-X 2.875 418707. 1048426.
FH 6 3 43130. 34780.~
16.60 18.62 IEU-G 2.625 462781. 976156.
6 3
18.39 IEU-G H90 3.125 462781. 938984. 43130. 39021 .p
NCSO(IF) 6% 3%
18.34 EU-G 3.625 462781. 939095. 43130. 37676. p
NC46(XH) 6% 3 43130.
18.88 IEU-G 2.875 462781. 1048426. 39659-p
6% 2%
16.60 19.28 IEU-S FH 2.375 595004. 1235337. 55453. 44769. p
6 3
18.42 IEU-S H90 2.875 595004. 938984. 55453. 39021 .p
6% 3%
18.61 EU-S NCSO(IF) 3.375 595004. 1109920. 55453. 44673. p
6% 2%
19.09 IEU-S NC46(XH) 2.625 595004. 1183908. 55453. 44871 .p
6 2%
20.00 22.29 IEU-X FH 2.375 522320. 1235337. 46741. 43247. b
21.79 I EU-X H90 3% 3.125 522320. 938984. 46741. 39021 .p
6% 3%
EU-X NCSO(IF) 3.375 522320. 1109920. 46741. 44673.~
22.13
6% 2%
22.56 I EU-X NC46(XH) 2.625 522320. 1183908. 46741. 44871 .p
2%
20.00 22.29 I EU-G FH 6 2.375 51661. 43247.b
577301. 1235337.
H90 6 3 2.875 577301. 1086246. 51661. 45258. p
21.90 IEU-G
NCSO(IF) 6% 3% 51661. 44673.~
22.13 EU-G 3.375 577301. 1109920.
6%
NC46(XH) 2% 51661. 49630-p
22.75 IEU-G 2.375 577301. 1307608.
6% 3 66421. 55708 .p
20.00 23.22 EU-S NCSO(IF) 2.875 742244. 1416225.
6% 2% 66421.
22.93 I EU-S NC46(XH) 2.125 742244. 1419527. 53936.p
6% 2%
22.82 25.43 IEU-X FH 2.125 596903. 1347256. 51821. 48912.~
6% 3% 51821.
24.58 EU-X NC5O(lF) 3.375 596903. 1109920. 44673.~
6% 2%
25.06 I EU-X NC46(XH) 2.625 596903. 1183908. 51821. 44871 .p
(Continued on page 16)
‘The torsional yield strength is based on a shear strength of 57.7% of the minimum yield strength.
*The tensile strength of the tool joint pin is based on 120,000 psi yield and the cross sectional area at the root of the
thread 5/s inch from the shoulder.
‘Tool Joint plus drill pipe, for Range 2 steel pipe (See Appendix A for method of calculation).
“See Par. 2.4.
f: p=pin limited yield. b=box limited yield. P or B indicates that tool joint could not meet 80% of tube torsion yield.
IS0 10407:1993(E)
RP 7G: Drill Stem Design and Operating Limits 17
TABLE 2.11 (continued)
MECHANICAL PROPERTIES OF NEW TOOL JOINTS
AND NEW HIGH STRENGTH DRILL PIPE
5 10 11 12
1 3 4 6 7 8 9
Mechanical Properties
Drill Pipe Data Tool Joint Data
I
\
A Drift I
. ‘\
/ \
Nom. Nom. Approx. Type Upset Diam- Tensile Yield, lb Torsional Yld., ft-lb
F r-.--,
eter”
and OD ID
Size Wt. Wt.’
Pipe *Tool Joint ‘Pipe Tool Joint’
Conn. in.
I b/ft I b/ft Pipe Grade in. in.
in.
4% 22.82 25.13 EU-G NC50( IF) 6% 3% 3.125 659735. 1268963. 57276. 51447.~
25.25 IEU-G NC46(XH) 6% 2% 2.375 659735. 1307608. 5727
...