EN ISO 10407-2:2008

SLOVENSKI STANDARD
01-december-2008
Industrija za predelavo nafte in zemeljskega plina - Rotacijska vrtalna oprema - 2.
del: Pregled in klasifikacija sestavnih delov vrtalnega vretena (ISO 10407-2:2008)
Petroleum and natural gas industries - Rotary drilling equipment - Part 2: Inspection and
classification of used drill stem elements (ISO 10407-2:2008)
Erdöl- und Erdgasindustrie - Bohr- und Produktionsausrüstung - Teil 2: Inspektion und
Klassifizierung von Bohrstrang-Komponenten (ISO 10407-2:2008)
Industries du pétrole et du gaz naturel - Équipement de forage rotatif - Partie 2: Contrôle
et classification des éléments de garnitures de forage usagés (ISO 10407-2:2008)
Ta slovenski standard je istoveten z: EN ISO 10407-2:2008
ICS:
75.180.10 Oprema za raziskovanje in Exploratory and extraction
odkopavanje equipment
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

EUROPEAN STANDARD
EN ISO 10407-2
NORME EUROPÉENNE
EUROPÄISCHE NORM
October 2008
ICS 75.180.10
English Version
Petroleum and natural gas industries - Rotary drilling equipment
- Part 2: Inspection and classification of used drill stem elements
(ISO 10407-2:2008)
Industries du pétrole et du gaz naturel - Équipement de Erdöl- und Erdgasindustrie - Bohr- und
forage rotatif - Partie 2: Contrôle et classification des Produktionsausrüstung - Teil 2: Inspektion und
éléments de garnitures de forage usagés (ISO 10407- Klassifizierung von Bohrstrang-Komponenten (ISO 10407-
2:2008) 2:2008)
This European Standard was approved by CEN on 27 September 2008.
CEN members are bound to comply with the CEN/CENELEC Internal Regulations which stipulate the conditions for giving this European
Standard the status of a national standard without any alteration. Up-to-date lists and bibliographical references concerning such national
standards may be obtained on application to the CEN Management Centre or to any CEN member.
This European Standard exists in three official versions (English, French, German). A version in any other language made by translation
under the responsibility of a CEN member into its own language and notified to the CEN Management Centre has the same status as the
official versions.
CEN members are the national standards bodies of Austria, Belgium, Bulgaria, Cyprus, Czech Republic, Denmark, Estonia, Finland,
France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta, Netherlands, Norway, Poland, Portugal,
Romania, Slovakia, Slovenia, Spain, Sweden, Switzerland and United Kingdom.
EUROPEAN COMMITTEE FOR STANDARDIZATION
COMITÉ EUROPÉEN DE NORMALISATION
EUROPÄISCHES KOMITEE FÜR NORMUNG
Management Centre: rue de Stassart, 36  B-1050 Brussels
© 2008 CEN All rights of exploitation in any form and by any means reserved Ref. No. EN ISO 10407-2:2008: E
worldwide for CEN national Members.

Contents Page
Foreword.3

Foreword
This document (EN ISO 10407-2:2008) has been prepared by Technical Committee ISO/TC 67 "Materials,
equipment and offshore structures for petroleum and natural gas industries" in collaboration with Technical
Committee CEN/TC 12 “Materials, equipment and offshore structures for petroleum, petrochemical and
natural gas industries” the secretariat of which is held by AFNOR.
This European Standard shall be given the status of a national standard, either by publication of an identical
text or by endorsement, at the latest by April 2009, and conflicting national standards shall be withdrawn at the
latest by April 2009.
Attention is drawn to the possibility that some of the elements of this document may be the subject of patent
rights. CEN [and/or CENELEC] shall not be held responsible for identifying any or all such patent rights.
According to the CEN/CENELEC Internal Regulations, the national standards organizations of the following
countries are bound to implement this European Standard: Austria, Belgium, Bulgaria, Cyprus, Czech
Republic, Denmark, Estonia, Finland, France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia,
Lithuania, Luxembourg, Malta, Netherlands, Norway, Poland, Portugal, Romania, Slovakia, Slovenia, Spain,
Sweden, Switzerland and the United Kingdom.
Endorsement notice
The text of ISO 10407-2:2008 has been approved by CEN as a EN ISO 10407-2:2008 without any
modification.
INTERNATIONAL ISO
STANDARD 10407-2
First edition
2008-10-15
Petroleum and natural gas industries —
Rotary drilling equipment —
Part 2:
Inspection and classification of used drill
stem elements
Industries du pétrole et du gaz naturel — Équipement de forage
rotatif —
Partie 2: Contrôle et classification des éléments de garnitures de forage
usagés
Reference number
ISO 10407-2:2008(E)
©
ISO 2008
ISO 10407-2:2008(E)
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©  ISO 2008
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ii © ISO 2008 – All rights reserved

ISO 10407-2:2008(E)
Contents Page
Foreword. vi
Introduction . vii
1 Scope .1
2 Normative references .1
3 Terms and definitions .2
4 Symbols and abbreviated terms .8
4.1 Symbols .8
4.2 Abbreviated terms .9
5 Conformance.10
5.1 Basis for inspection .10
5.2 Repeatability of results .11
5.3 Ordering information.11
6 Quality assurance.11
6.1 General.11
6.2 Standardization and operating procedures .11
6.3 Equipment description.12
6.4 Personnel qualification .12
6.5 Dynamic test data demonstrating the system capabilities for detecting the reference
indicators.12
6.6 Reports .12
7 Qualification of inspection personnel .12
7.1 General.12
7.2 Written procedure.12
7.3 Qualification responsibility and requirements .13
7.4 Training programmes.13
7.5 Examinations.13
7.6 Experience.13
7.7 Re-qualification.13
7.8 Documentation.14
7.9 NDT personnel certification.14
8 General inspection procedures.14
8.1 General.14
8.2 Owner/operator work site requirements for quality inspection.14
8.3 Documents at job site .14
8.4 Pre-inspection procedures .15
8.5 Drill-pipe and tool-joint classification markings .15
8.6 Post-inspection procedures .16
9 General non-destructive inspection method requirements .19
9.1 General.19
9.2 Equipment .19
9.3 Illumination.20
9.4 Magnetic-particle-inspection equipment.21
9.5 Ultrasonic .23
9.6 Electromagnetic inspection units .24
10 Drill stem element inspection and classification .24
10.1 Pipe body — Full-length visual inspection .24
10.2 Drill body — Outside diameter gauging .25
ISO 10407-2:2008(E)
10.3 Pipe body — Ultrasonic wall-thickness gauging. 27
10.4 Pipe body — Full-length electromagnetic inspection (EMI) . 29
10.5 Pipe body — Full-length ultrasonic transverse and wall thickness . 31
10.6 Pipe body — Full-length ultrasonic transverse, wall thickness and longitudinal inspection. 34
10.7 Drill-pipe body — External magnetic-particle inspection of the critical area . 37
10.8 Drill-pipe body — Bi-directional external magnetic-particle inspection of the critical area . 40
10.9 Pipe body — Full-length wall-loss inspection. 43
10.10 Pipe body — Ultrasonic inspection of the critical area. 46
10.11 Pipe body — Calculation of cross-sectional area. 49
10.12 Pipe body — Document review (traceability). 50
10.13 Pipe body — Evaluation and classification. 50
10.14 Tool joints . 55
10.15 Tool joints — Check for box swell and pin stretch. 60
10.16 Repair of rejected tool joints. 61
10.17 Tool joints — Check tool-joint pin and box outside diameter and eccentric wear . 61
10.18 Tool joints — Measure tool-joint pin and box outside diameter and check for eccentric
wear . 64
10.19 Tool joints — Check tool-joint pin and box tong space. 65
10.20 Tool joints — Measure tool-joint pin and box tong space. 66
10.21 Tool joint — Magnetic-particle inspection of the pin threads . 67
10.22 Tool joint — Magnetic-particle inspection of box threads. 69
10.23 Tool joints — Measure tool-joint pin inside diameter . 70
10.24 Magnetic-particle inspection of the connection OD for heat-check cracking . 71
10.25 Bi-directional wet magnetic-particle inspection of the connection OD for heat-check
cracking. 72
10.26 Tool joints — Measure the tool-joint counterbore depth, pin-base length and seal width . 76
10.27 BHA connection — Visual inspection of bevels, seals, threads and stress-relief features. 77
10.28 BHA — Measure box outside diameter, pin inside diameter, counterbore diameter and
benchmark location if a benchmark is present. 80
10.29 BHA — Check bevel diameter. 82
10.30 BHA — Measure bevel diameter. 83
10.31 BHA — Magnetic-particle inspection of the pin and box threads. 84
10.32 BHA connection — Liquid-penetrant inspection of the pin and box threads. 86
10.33 BHA — Dimensional measurement of stress-relief features. 88
10.34 Length measurements of the counterbore, pin and pin neck . 90
10.35 Drill collar — Visual full-length OD and ID, markings, fish-neck length and tong space. 91
10.36 Drill-collar elevator groove and slip-recess magnetic-particle inspection . 92
10.37 Drill-collar elevator-groove and slip-recess measurement . 95
10.38 Subs (full-length visual OD and ID), fish-neck length, section-change radius and markings . 96
10.39 Float-bore recess measurements. 97
10.40 Magnetic-particle inspection of subs — Full-length, internal and external . 99
10.41 HWDP — Visual full-length OD and ID, markings and tong space . 101
10.42 Visual inspection and wear pattern report for kelly . 102
10.43 Magnetic-particle evaluation of critical areas on kellys. 104
10.44 Magnetic-particle evaluation, full length, of the drive section on kellys. 104
10.45 Stabilizer (full-length visual OD and ID), fish-neck length, blade condition, ring gauge and
markings . 104
10.46 Magnetic-particle inspection of the base of stabilizer blades for cracking . 106
10.47 Function test. 108
10.48 Bi-directional, wet magnetic-particle inspection of the base of stabilizer blade for
cracking. 109
10.49 Visual inspection of jars (drilling and fishing), accelerators and shock subs . 112
10.50 Maintenance review . 113
10.51 Dimensional measurement of wear areas as specified by OEM requirements . 113
10.52 Original equipment manufacturer designated testing for used equipment. 114
10.53 MWD/LWD — Visual, full-length OD and ID, and markings, including visual inspection of
hard-banding and coatings. 114
10.54 Motors and turbines — Visual, full-length OD and ID and markings, including visual
inspection of hard-banding and coatings . 116
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ISO 10407-2:2008(E)
10.55 Reamers, scrapers, and hole openers — Visual, full-length OD and ID and markings,
including visual inspection of hard-banding and coatings.117
10.56 Rotary steerable — Visual, full-length OD and ID and markings, including visual
inspection of hard-banding .118
10.57 Full-length drift.119
10.58 Proprietary equipment inspection .120
10.59 Hard-banding inspection .121
10.60 Transverse magnetic-particle inspection of tool-joint OD and ID under the pin threads .124
10.61 Drill-pipe body — Internal magnetic-particle inspection of the critical area.126
10.62 Drill-pipe body — Bi-directional, internal magnetic-particle inspection of the critical area.128
10.63 API external upset-thread connection inspection.130
Annex A (normative) Original equipment manufacturer (OEM) requirements .132
Annex B (normative) Required and additional inspections by product and class of service.134
Annex C (normative) SI units .144
Annex D (informative) USC units .173
Annex E (informative) Inspection-level guidelines .202
Annex F (informative) Proprietary drill stem connection inspection.206
Annex G (informative) Used work-string tubing proprietary-connection thread inspection.211
Bibliography .213

ISO 10407-2:2008(E)
Foreword
ISO (the International Organization for Standardization) is a worldwide federation of national standards bodies
(ISO member bodies). The work of preparing International Standards is normally carried out through ISO
technical committees. Each member body interested in a subject for which a technical committee has been
established has the right to be represented on that committee. International organizations, governmental and
non-governmental, in liaison with ISO, also take part in the work. ISO collaborates closely with the
International Electrotechnical Commission (IEC) on all matters of electrotechnical standardization.
International Standards are drafted in accordance with the rules given in the ISO/IEC Directives, Part 2.
The main task of technical committees is to prepare International Standards. 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.
Attention is drawn to the possibility that some of the elements of this document may be the subject of patent
rights. ISO shall not be held responsible for identifying any or all such patent rights.
ISO 10407-2 was prepared by Technical Committee ISO/TC 67, Materials, equipment and offshore structures
for petroleum, petrochemical and natural gas industries, Subcommittee SC 4, Drilling and production
equipment.
This first edition of ISO 10407-2, together with ISO 10407-1, replaces ISO 10407:1993, which will be
cancelled when both ISO 10407-1 and ISO 10407-2 have been published and which has been technically
revised.
ISO 10407 consists of the following parts, under the general title Petroleum and natural gas industries —
Rotary drilling equipment:
⎯ Part 2: Inspection and classification of used drill stem elements
A Part 1, dealing with drill stem design and operating limits, is under development.
vi © ISO 2008 – All rights reserved

ISO 10407-2:2008(E)
Introduction
Users of this International Standard should be aware that further or differing requirements can be needed for
individual applications. This International Standard is not intended to inhibit a vendor from offering, or the
purchaser from accepting, alternative equipment or engineering solutions for the individual application. This
can be particularly applicable where there is innovative or developing technology. Where an alternative is
offered, the vendor should identify any variations from this International Standard and provide details.
This International Standard shall become effective on the date printed on the cover but may be used
voluntarily from the date of distribution.
This International Standard includes provisions of various natures. These are identified by the use of certain
verbal forms:
⎯ SHALL is used to indicate that a provision is MANDATORY;
⎯ SHOULD is used to indicate that a provision is not mandatory, but RECOMMENDED as good practice;
⎯ MAY is used to indicate that a provision is OPTIONAL;
⎯ CAN is used to indicate a POSSIBILITY.

INTERNATIONAL STANDARD ISO 10407-2:2008(E)

Petroleum and natural gas industries — Rotary drilling
equipment —
Part 2:
Inspection and classification of used drill stem elements
1 Scope
This part of ISO 10407 specifies the required inspection for each level of inspection (Tables B.1 through B.15)
and procedures for the inspection and testing of used drill stem elements. For the purpose of this part of
ISO 10407, drill stem elements include drill pipe body, tool joints, rotary-shouldered connections, drill collar,
HWDP and the ends of drill stem elements that make up with them. This part of ISO 10407 has been prepared
to address the practices and technology commonly used in inspection.
The practices established within this part of ISO 10407 are intended as inspection and/or testing guidance and
are not intended to be interpreted to prohibit the agency or owner from using personal judgement,
supplementing the inspection with other techniques, extending existing techniques or re-inspecting certain
lengths.
This part of ISO 10407 specifies the qualification of inspection personnel, a description of inspection methods
and apparatus calibration and standardization procedures for various inspection methods. The evaluation of
imperfections and the marking of inspected drill stem elements is included.
This part of ISO 10407 provides the original equipment manufacturers' requirements regarding the minimum
information needed for the inspection of their specialized tools in Annex A.
2 Normative references
The following referenced documents are indispensable for the application of this document. For dated
references, only the edition cited applies. For undated references, the latest edition of the referenced
document (including any amendments) applies.
ISO 10424-1, Petroleum and natural gas industries — Rotary drilling equipment — Part 1: Rotary drill stem
elements
4)
ISO 11961 , Petroleum and natural gas industries — Steel drill pipe
API RP 7A1, Testing of Thread Compound for Rotary Shouldered Connections

4) To be published. (Revision of ISO 11961:1996, Petroleum and natural gas industries — Steel pipes for use as drill
pipe — Specification)
ISO 10407-2:2008(E)
3 Terms and definitions
For the purposes of this document, the following terms and definitions apply.
3.1
agency
entity contracted to inspect used drill stem elements using the methods and criteria specified
3.2
A-scan
ultrasonic instrument display where distance is represented on the horizontal axis and signal strength on the
vertical axis
3.3
bending-strength ratio
BSR
ratio of the section modulus of the box thread at its last engaged thread to the pin thread at its last engaged
thread
3.4
bevel diameter
outer diameter of the contact face of the rotary shouldered connection
3.5
bit sub
sub, usually with two box connections, that is used to connect the bit to the drill stem
3.6
bottleneck sub
sub with two distinct outside diameters
3.7
box end
end of pipe with internal threads
3.8
box thread
internal (female) threads of a rotary shouldered connection
3.9
class 2
second in the hierarchy of used drill pipe service classifications for used drill pipe that does not meet premium
class requirements
3.10
class 3
third in the hierarchy of used drill pipe service classifications for used drill pipe that does not meet class 2
requirements
3.11
calibration
adjustment of instruments to a known basic reference often traceable to the national standards body
NOTE Calibration typically is documented in a log book and by a tag applied to the instrument.
3.12
check
go/no-go determination that dimension is within tolerances
2 © ISO 2008 – All rights reserved

ISO 10407-2:2008(E)
3.13
corrosion
alteration and degradation of material by its environment
3.14
critical area
area from the base of the tapered shoulder of the tool joint to a plane located 660 mm (26.0 in) away, or the
end of the slip marks, whichever distance is greater
See Figure 4.
NOTE When applied to the work-string tubing area, it is from the end of the pipe to a plane located 508 mm (20 in)
away, or the end of the slip marks, whichever distance is greater.
3.15
cut
incision without removal of metal caused by a sharp object
3.16
dent
local change in surface contour caused by mechanical impact, but not accompanied by loss of metal
3.17
drift
cylindrical gauge used to check the minimum inside diameter
3.18
drill collar
thick-walled pipe or tube designed to provide stiffness and concentration of mass at or near the bit
3.19
drill pipe
drill pipe body with weld-on tool joints
See Figure 1.
3.20
drill-pipe body
seamless steel pipe with upset ends
See Figure 1.
3.21
drill stem
all members between the swivel or top drive and the bit; includes drill string
3.22
drill string
several sections or joints of drill pipe with the tool joints that are joined together
3.23
failure
improper performance of a device or equipment that prevents completion of its design function
3.24
fatigue
process of progressive localized permanent structural change occurring in a material subjected to conditions
that produce fluctuating stresses and strains at some point or points and that can culminate in cracks or
complete fracture after a sufficient number of fluctuations
ISO 10407-2:2008(E)
3.25
fatigue failure
failure that originates as a result of repeated or fluctuating stresses having maximum values less than the
tensile strength of the material
3.26
fatigue crack
crack resulting from fatigue
3.27
filtered FWAC
full-wave current rectified by passing it through a capacitor or other electrical device to remove the fluctuations
associated with alternating current
3.28
fish neck
region with a reduced diameter at or near the upper end of a drill string member which fishing tools can grab
3.29
full-depth thread
thread for which the thread root lies on the minor cone of an external thread or lies on the major cone of an
internal thread
3.30
gall
surface damage on threads and seals caused by localized friction
3.31
gouge
elongated grooves or cavities caused by mechanical removal of metal
3.32
grind, noun
area where metal was removed with an abrasive wheel in the process of evaluation or repair on an
imperfection
3.33
hard-banding
hard-facing
sacrificial or wear-resistant material applied to component’s surface to prevent wear of the component
3.34
heat checking
formation of surface cracks formed by the rapid heating and cooling of the component
3.35
heavy-weight drill pipe
HWDP
pipe with thick wall used in the transition zone to minimize fatigue and as bit weight in directional wells
3.36
inspection
process of measuring, examining, testing, gauging or otherwise comparing the product with the applicable
requirements
3.37
jar
mechanical or hydraulic device used in the drill stem to deliver an impact load to another component of the
drill stem, especially when that component is stuck
4 © ISO 2008 – All rights reserved

ISO 10407-2:2008(E)
3.38
kelly
square- or hexagonal-shaped steel pipe connecting the swivel to the drill pipe
NOTE The kelly moves through the rotary table and transmits torque to the drill stem.
3.39
label
dimensionless designation for the pipe body size, pipe body mass per unit length or the size and style of a
rotary shouldered connection
3.40
last engaged thread
last thread on the pin engaged with the box or the box engaged with the pin
See Figure 2.
3.41
lead
distance parallel to the thread axis from a point on a thread turn and the nearest corresponding point on the
next turn, i.e. the axial displacement of a point following the helix one turn around the thread axis
3.42
lower kelly valve
kelly cock
essentially full-opening valve installed immediately below the kelly, with outside diameter equal to the tool joint
outside diameter
NOTE The valve can be closed to remove the kelly under pressure and can be stripped in the hole for snubbing
operations.
3.43
make-up shoulder
sealing shoulder on a rotary shouldered connection
3.44
measure
determining of dimensional value and recording of it on a worksheet
3.45
mill slot
flat machined area on the outside diameter of a tool joint where grade, weight code and optional serial number
information is stamped
3.46
owner
company or person who specifies the type of inspection or testing to be conducted and who has the authority
to order it performed
3.47
pi tape
flexible steel tape that, when wrapped around the circumference of a cylinder, indicates the average outside
diameter
3.48
pin base
non-threaded area at the large end of the pin connection adjacent to the shoulder
ISO 10407-2:2008(E)
3.49
pin end
end of the pipe with external threads
3.50
pipe body
seamless steel pipe excluding upset and upset-affected areas
See Figure 1.
3.51
pit
depression resulting from corrosion or removal of foreign material rolled into the surface during manufacture
3.52
pitch
axial distance between successive threads
NOTE In a single start thread, pitch is equivalent to lead.
3.53
premium class
highest in the hierarchy of used drill pipe service classifications, better than class 2 and class 3
3.54
quality programme
established documented system for ensuring quality
3.55
rotary shouldered connection
connection used on drill stem elements that have coarse, tapered threads and sealing shoulders
3.56
seamless pipe
wrought steel tubular product made without a weld seam
3.57
slip area
that part of the pipe body where there is visible evidence of the trip slips having been repeatedly set numerous
times in the same area
See Figure 4.
NOTE At the upper end, it is typically located approximately 560 mm (22 in) from the box-tool joint elevator shoulder,
and extends from that point approximately 660 mm (26 in) toward the pin end. It can be located elsewhere depending on
rig design and positioning of handling equipment. It does not include occasional setting of slips in other areas as a result of
fishing operations, drill stem tests and similar applications.
3.58
stabilizer
member of the drill stem assembly used to centralize or control the direction of the bottom-hole assembly
3.59
straight sub
sub with no outside diameter change
3.60
standardization
adjustment of instruments prior to use to an arbitrary reference value
6 © ISO 2008 – All rights reserved

ISO 10407-2:2008(E)
3.61
sub
short, threaded piece of pipe used to connect parts for the drilling assembly for various reasons, such as
crossing over to a different connection, or to save wear and tear on more expensive elements
3.62
thread form
thread profile in an axial plane for a length of one pitch
3.63
tolerance
amount of variation permitted
3.64
upper kelly cock
valve immediately above the kelly that can be closed to confine pressure inside the drill stem
3.65
upset
forged end of a drill pipe tube used to increase wall thickness
3.66
user
company or person who employs the equipment
3.67
weight code
unique numerical code for each outside diameter of drill pipe, normally stamped on the pin base and in the mill
slot, which provides wall thickness and pipe body mass per unit length information

Key
1 drill pipe 4 tool joint pin
2 tool joint box 5 pipe body
3 drill pipe body 6 weld
Figure 1 — Drill-pipe nomenclature
ISO 10407-2:2008(E)
Key
1 last engaged thread – pin
2 last engaged thread – box
3 bevel diameter, D
F
4 seal
Figure 2 — Last engaged threads
4 Symbols and abbreviated terms
4.1 Symbols
A cross-sectional area
CS
D outside diameter
D diameter of counterbore
cb
D bevel diameter
F
D diameter of float bore recess
FR
D diameter of pin base
L
D diameter of low-torque counterbore
LTorq
D diameter of stress-relief groove
RG
D outside diameter of tool joint
tj
d inside diameter of tool joint
tj
l elevator groove depth
e
l slip groove depth
s
L length of box connection
BC
L length of baffle recess
br
L length from shoulder to non-pressure flank on last full-depth thread box
BT
L minimum-length full-crested threads
c
L length from last scratch to beginning of the tapered section of boreback
Cyl
L length of elevator groove
eg
L length of fish neck
fn
L length of pin thread
PC
L length of pin base
pb
8 © ISO 2008 – All rights reserved

ISO 10407-2:2008(E)
L length of counterbore
qc
L length float-bore recess
R
L length of stress-relief groove
RG
L length of slip groove
sg
L length of tapered section of boreback
Tpr
L length from shoulder to last thread scratch in boreback cylinder
X
Q counterbore diameter
c
r elevator groove radius
EG
r slip groove radius
SG
S shoulder width
w
t average wall thickness
4.2 Abbreviated terms
AC alternating current
dB decibels
BHA bottom-hole assembly
BSR bending-strength ratio
DC direct current
EBW effective beam width
EMI electromagnetic inspection
EUE external upset ends
FF full face
FLUT full-length ultrasonic transverse
FSH full screen height
FWAC full-wave rectified alternating current
HWAC half-wave alternating current
HWDP heavy-weight drill pipe
ID inside diameter
LT low torque
LWD logging while drilling
MT magnetic-particle inspection
MWD measuring while drilling
NDT non-destructive testing
NI ampere turns
OBM oil-based mud
OD outside diameter
OEM original equipment manufacturer
PD pulse density
PT liquid penetrant inspection
S/N signal-to-noise ratio
ISO 10407-2:2008(E)
SOBM synthetic oil-based mud
SRG stress-relief groove
SWBM synthetic water-based mud
TJ tool joint
TPR taper
UDP used drill pipe
UT ultrasonic inspection
WBM water-based mud
µW microwatts
5 Conformance
5.1 Basis for inspection
5.1.1 General
This part of ISO 10407 contains practices for use in the inspection, evaluation and classification of used drill
stem elements. Guidelines to assist the user in determining the appropriate level of inspection are provided in
Annex E.
The inspections for each level of inspection are shown in Annex B; these practices can be placed in one of the
following levels.
a) Inspections shown under the standard inspection that are specified as mandatory for classification
constitute the minimum inspection requirements for classification of the drill stem element.
b) Inspections that are specified as mandatory for classification when moderate service inspection is
specified constitute minimum inspection requirements for classification of the drill stem element according
to moderate service inspection requirements.
c) Inspections that are specified as mandatory for classification when critical service inspection is specified
constitute minimum inspection requirements for classification of the drill stem element according to critical
service inspection requirements.
d) Inspections that are not specified as mandatory may be specified based on drilling conditions.
5.1.2 Required inspection tables in Annex B
The tables in Annex B list the required inspections for each of the above levels inspection. The following is a
list of drill stem elements covered in the tables in Annex B.
⎯ Table B.1 identifies the inspections available and specifies which inspections are required for each level
of inspection for used drill pipe bodies, as well as the additional services available.
⎯ Table B.2 identifies the inspections available and specifies which inspections are required for each level
of inspection for used tool joints, as well as the additional services available.
⎯ Table B.3 identifies the inspections available and specifies which inspections are required for each level
of inspection for connections used on bottom-hole assemblies, as well as the additional services available.
⎯ Tables B.4 through B.14 identify the inspections available and specify which inspections are required for
each level of inspection for bottom-hole-assembly drill stem elements other than connection inspections,
as well as the additional services available
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