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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 1 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
STANDARD OPERATING PROCEDURE
FOR
VISUAL AND DIMENSIONAL INSPECTION NOTE: This document is
considered COMPANY CONFIDENTIAL and is not to be distributed
in whole or in part outside the Company, without the express,
written consent of the undersigned authority.
PROCEDURE APPROVAL: ___________________________ DATE:
_____________
Vice President Inspection & Coating Product Line PROCEDURE
APPROVAL: ___________________________ DATE: ______________ Director
Quality & Technical Services
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 2 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
INTRODUCTION This procedure establishes minimum requirements for
the dimensional measurement of tool joints on drill pipe and heavy
weight drill pipe (HWDP). The purpose is for proper classification
of the tool joint in accordance with the parameters set forth in
API RP 7G, DS-1 or NS-2. This procedure also establishes minimum
requirements for the dimensional measurement of rotary shouldered
connections on drill pipe, HWDP, drill collars and other components
of the Bottom Hole Assembly (BHA). Additionally, this procedure
establishes the minimum requirements for the visual inspection and
O.D. gauging of the pipe body on drill pipe.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 3 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
TABLE OF CONTENTS 1.0
Scope............................................................................................................................................
5 1.2.1 Tool
Joints........................................................................................................5
1.2.3
BHA..................................................................................................................5
2.0 Personnel
Requirements..............................................................................................................
6 3.0 Equipment
Requirements.............................................................................................................
6 3.7 Lead
Gauge........................................................................................................................
7 3.7.3 Lead Gauge Contact Points
................................................................................
8 3.8 Visible Light
Sources.........................................................................................................
8 3.9 Equipment
Calibration........................................................................................................
8 4.0 Surface
Preparation......................................................................................................................
8 5.0 Inspection
Procedure....................................................................................................................
8 5.3 Weight and Grade
Verification..........................................................................................
9 5.5 Visual
Connection..............................................................................................................
9 5.5.1 Shoulder (Face)
....................................................................................................
9 5.5.2 Thread
Inspection...............................................................................................
10 5.5.3 Bevel
...................................................................................................................
11 5.5.4 Box Outside Diameter Swell (Tool Joints
only)................................................ 11 5.5.5 Box
Diameter Swell (Drill Collars and BHA Components only)
...................... 11 5.5.6 Shoulder Flatness
..........................................................................................11
5.5.7 Thread
Profile.....................................................................................................
11 5.5.8 Hard-banding
.................................................................................................11
5.6 Tool Joint Dimensional Measurements
..........................................................................
12 5.6.1 Outside Diameter
...............................................................................................
12 5.6.2 Pin Inside
Diameter........................................................................................12
5.6.3 Bevel
Diameter...............................................................................................12
5.6.4 Tong
Space....................................................................................................12
5.6.5 Box Shoulder Width
.......................................................................................13
5.6.6 Pin Neck
Length.............................................................................................13
5.6.7 Box Seal
Width...............................................................................................13
5.6.8 Box Counterbore Diameter (Swell)
................................................................13
5.6.9 Box Counterbore Depth
.................................................................................13
5.6.10 Pin Lead
.........................................................................................................13
5.7 Drill Collars and BHA Components
.............................................................................14
5.7.1 Box Outside Diameter
....................................................................................14
5.7.2 Pin Inside
Diameter........................................................................................14
5.7.3 Pin Length
......................................................................................................14
5.7.4 Pin Relief Groove Diameter
...........................................................................14
5.7.5 Pin Relief Groove
Width.................................................................................14
5.7.6 Box Counterbore Diameter
............................................................................14
5.7.7 Boreback Diameter
........................................................................................14
5.7.8 Boreback Length
............................................................................................15
5.7.9 Box Counterbore Depth
.................................................................................15
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 4 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
5.7.10 Boreback Thread
Length................................................................................15
5.7.11 Pin Neck
Length.............................................................................................15
5.7.12 Mid Tube Upset Diameter of HWDP
..............................................................15
5.7.13 Mid Tube Upset Height of HWDP
..................................................................15
5.8 Tube Body
Inspections....................................................................................................
16 5.8.1 Visual
.............................................................................................................16
5.8.2 Straightness
.......................................................................................................
16 5.9 O.D.
Gauging...................................................................................................................
16 5.9.1 Surface
Condition...........................................................................................16
5.9.2
Standardization...............................................................................................16
5.9.6 Slip/Critical Area Gauging
...............................................................................18
5.9.7 Measuring Mechanical
Damage.........................................................................
18 6.0 Field Refacing of Used Tool Joint
Shoulders.............................................................................
18 6.1 Bench
Mark......................................................................................................................
18 6.4 Shoulder Face
Bevel........................................................................................................
19 6.5 Coating of Shoulder Face
................................................................................................
20 7.0 Classification of Tool Joints and Rotary Shouldered
Connections............................................ 20 7.1 Tool
Joints
........................................................................................................................
20 7.2 Drill Collars
.......................................................................................................................
20 7.3
HWDP...............................................................................................................................
20 7.4 Shoulders
.........................................................................................................................
20 8.0 Post Inspection Procedures
.......................................................................................................
21 Table 1.2 - Dimensional and Visual Inspection Attributes
...................................................................
22 Figure
1.2.a...........................................................................................................................................
23 Figure
1.2.b...........................................................................................................................................
24 Table 3.7.3 - Gauge Contact Point
Diameter.......................................................................................
24 Figure 5.3.2-1 Old API Marking System for Drill
Pipe.......................................................................
25 Figure 5.3.2-2 New API Marking System for Standard Wall Drill
Pipe............................................. 25 Figure 5.3.2-3
New API Marking System for Heavy Wall Drill Pipe
................................................. 26 Figure 5.3.2-4
New API Marking System for Thick Wall Drill Pipe
................................................... 26 Figure
5.3.2-5 New API Marking System for Standard Wall Drill
Pipe............................................. 27 Table 5.7.13
Heavy Weight Drill Pipe Center Upset
Dimensions.....................................................
28
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 5 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
1.0 SCOPE 1.1 This procedure establishes minimum requirements
for the dimensional
measurement of tool joints on drill pipe and heavy weight drill
pipe (HWDP). The purpose is for proper classification of the tool
joint in accordance with the parameters set forth in API RP 7G.
This procedure also establishes minimum requirements for the
dimensional measurement of rotary shouldered connections on drill
pipe, HWDP, drill collars and other components of the Bottom Hole
Assembly (BHA). Additionally, this procedure establishes the
minimum requirements for the visual inspection and O.D. gauging of
the pipe body on drill pipe.
1.2 Specifically, this inspection covers those items indicated
as Required and
Optional in API RP 7G. Additionally, this procedure covers the
three (3) Dimensional Inspections contained in DS-1. The customer
should be consulted, to determine the level of visual inspection
service required. Refer to Table 1.2 and Figures 1.2 a. and 1.2 b.
for a breakdown and diagram of the details.
1.2.1 Tool Joints. Unless specified otherwise by the customer,
only the items
identified under API RP 7G - Required in Table 1.2 must be
performed. 1.2.2 API RP 7G - Optional, Dimensional 1 and
Dimensional 2 are invoked
only by customer request. 1.2.3 BHA. Includes Drill Collars,
HWDP, Drilling Jars, Saver Subs,
MWD/LWD Tools, mud motors, turbines, Stabilizers, Under reamers,
Hole Openers, Roller Reamers, Casing Scrapers and Subs. For these
components, all items identified under Dimensional 3 shall be
performed.
1.2.4 Surface Safety Valves, Kelly Valves and Inside Blowout
Preventers
(IBOPs). For these components, all items identified under
Dimensional 2 shall be performed.
1.3 The measured dimensions obtained during the inspections
described in this
SOP are not required to be documented on the Tuboscope Drill
Pipe Inspection Report, unless specified in the applicable section
of this SOP or when specified by the customer.
1.4 This Tuboscope document is the controlling document whenever
any other like
kind prior-dated Tuboscope inspection procedures are in
conflict.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 6 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
1.5 The latest revision of the following documents were used as
references for
establishing this procedure: 1.5.1 API Specification 7 - Rotary
Drill Stem Elements. 1.5.2 API Recommended Practice 7G - Drill Stem
Design and Operating
Limits. 1.5.3 SOP III-001 - General Requirements. 1.5.4 SOP
III-403 Manual Ultrasonic Thickness Gauging.
1.5.5 Applicable Tuboscope Division Operating Procedure for
Straightening Drill Pipe.
1.5.6 DS-1 - Drill Stem Design and Inspection. 1.5.7 NS-2 North
Sea Drillstring Inspection Standard. 2.0 PERSONNEL REQUIREMENTS
Personnel performing the inspection techniques outlined in this
procedure shall be qualified in Used Drill Pipe Inspection (code
46) and Bottom Hole Assembly Inspection (code 47) in accordance
with 4.0 of SOP III-001.
3.0 EQUIPMENT REQUIREMENTS 3.1 A 12 inch steel rule with
graduations in 1/64 inch (0,5 mm) units. 3.2 External (OD) spring
calipers capable of expanding beyond the new diameter of
the tool joint. 3.3 Internal (ID) spring calipers capable of
expanding beyond the maximum inside
diameter of the material being inspected. 3.3.1 Electronic, dial
or vernier type calipers may also be used for measuring
purposes. 3.4 A small, flat, non-tinted mirror for observing the
load flanks and roots of the
internal threads.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 7 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
3.5 Horse shoe shaped outside diameter gauge capable of
measuring diameter
reductions in 1/32 inch increments. The gauge shall have a
maximum spacing of nominal diameter plus 1/32 inch if oversize
gauging is required. In all other instances the gauge shall be
capable of measuring nominal pipe diameter minus 5/32 inches.
3.5.1 Check the faces of side wear blocks and center wear blocks
for excessive
wear. 3.5.2 Check the movable plunger alignment. a. No side
play. b. Free movement in the slot.
3.5.3 The appropriate setting standard for the specified pipe
size is required for gauge set up. The length of the gauge bar
standard is 1/32 inch (0,79 mm) less than the specified OD of the
pipe. This standard shall be verified with a precision caliper or
micrometer prior to use.
3.5.4 As an alternative, the gauge may be set up with a
dial/vernier caliper or
inside micrometer. 3.5.5 As an alternative to a diameter gauge,
an external spring caliper, set up
with an electronic, dial or vernier caliper may also be used to
check for diameter reductions.
3.6 The applicable API rotary shoulder connection (RSC) hardened
and ground
profile gauge. 3.7 Lead Gauge
3.7.1 The gauge for measuring lead tolerance is equipped with
two (2) contact
points and a balance dial type indicator. Several types of
gauges are available:
a. External-internal, RSC sizes 4-1/2 inch and larger. b.
Universal gauges are available for all RSC sizes. 3.7.2 A lead
setting standard is also required. The setting standard shall
be
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 8 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
appropriate for the thread pitch and thread taper. 3.7.3 Lead
Gauge Contact Points. The diameters of contact points shall
meet
the requirements of Table 3.7.3. Ball type contact points shall
be visually examined for evidence of wear on the points of the ball
which contact the thread surface. Worn contacts points shall be
replaced regardless of actual diameter.
3.8 Visible Light Sources. Overhead lighting, hand held white
light fixtures and light
meters shall meet the requirements in 9.0 of SOP III-001. 3.9
Equipment Calibration. Equipment calibration/verification shall be
in accordance
with 9.1 of SOP III-001.
3.9.1 Calipers, micrometers, Lead gauge setting standards and
Lead gauges shall be calibrated after any repairs and at the
frequency specified in Table 9.1 in SOP III-001.
4.0 SURFACE PREPARATION
4.1 Thread protectors shall be removed and cleaned (if required)
in accordance with 14.0 in SOP III-001. If the customer requires
optional sandblasting prior to inspection, thread protectors shall
remain installed until the sandblasting operation is completed.
4.2 Thread compound, grease and other hard foreign deposits,
shall be removed
from surfaces to be inspected.
4.3 All excessive amounts of rust, dirt, grease, oil or applied
coatings shall be removed prior to O.D. gauging.
4.4 Scale should be evaluated in accordance with 10.1.1 in SOP
III-001. Internal
coatings should be graded in accordance with DS-1, par. 3.4.4.f
or NS-2, Appendix 8.
5.0 INSPECTION PROCEDURE
5.1 Material identification shall be in accordance with 11.0 in
SOP III-001. 5.2 The appropriate information shall be completed on
the Drill Pipe Inspection Tally
sheet for applicable information and dimensions from this
section.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 9 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
5.3 Weight and Grade Verification. The tool joint weld date and
grade mark
inspection consists of a visual examination to determine pipe
age, grade, weight, and past tool joint rework.
5.3.1 The base of each pin must be cleaned as necessary to allow
visual
inspection of the surface for the manufacturers markings. (These
markings are stamped on the base of the pins when the tool joints
are welded onto the pipe.)
5.3.2 Check each pin base (neck) or milled slot for the
following markings as
illustrated in Figure 5.3.2-1 through 5.3.2-5 a. Manufacturers
Symbol b. Date of tool joining c. Grade of Drill Pipe d. Weight of
Drill Pipe NOTE: The absence of these markings indicates that the
tool joints may have been
reworked. This should be noted on the inspection report. 5.4
Refer to Table 1.2 for the appropriate items from this section to
be inspected. 5.5 Visual Connection NOTE: Sections 5.5 and 5.6 are
intended for API and Similar Non-proprietary
Connections. For GrantPrideco; Hi Torque, eXtreme Torque, Double
Shoulder, XT-M, OMSCO TuffTorq and Hydril Wedge Thread connections,
refer to the applicable manufacturers documentation, DS-1 or
contact QTS for information on visual and dimensional inspection of
these connections.
5.5.1 Shoulder (Face). Visually inspect shoulder on both the pin
and box
connections for damage that may prevent proper make-up or
pressure seal. The sealing shoulder must be relatively smooth to
resist a leak path. Inspect for galls, nicks, fins, washes or any
other matter or deformation which would affect the ability of the
stability or pressure holding capacity of the connection.
Classification of shoulder damage is subjective and requires a
degree of
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 10 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
judgment, experience and, if possible, knowledge of the drill
pipe strings performance history. If the performance history, or
visual examination indicates a significant number of shoulder leaks
and/or washes; it may be possible that conditions other than
shoulder damage could be contributing to the leaks and washes. In
that case, minor cuts, dents, scars or washes which extend
radically across the shoulder face should be viewed with critical
judgment. On the other hand, if performance history or visual
examination indicates very little or no leakage or washing, minor
damage may be viewed with less critical judgment. The inspector
should be aware that the presence of thread compound helps seal
minor leak paths against pressure, but also that shoulder face is
the only seal against pressure in the tool joint design.
If damage is present classify in accordance with Table 18.2.3 in
SOP III-
001.
5.5.2 Thread Inspection. Visually inspect the entire thread
surfaces of both the pin and box connections for pitting, galling,
lapped threads, rolled pressure flanks, broken threads, washed
shoulder, washed threads, flank wear and other mechanical damage
that may prevent proper make-up or pressure seal. Inspect the box
threads using an inspection mirror.
Tool joint threads do not seal, therefore minor imperfections
and damage
on the threads is not cause for rejection. On the other hand,
some protrusions on thread flanks can interfere with make-up and
should be rejected or repaired. The Inspector should exercise good
judgment in these matters.
a. Protrusions from thread crests or flanks are cause for
rejection and
shall be marked as field repairable. When approved by the
customer, minor repair of thread crests and flanks threads may be
performed with caution. The pressure flanks are the most critical
to maintain a tight wobble-free connection. The inspection may be
less critical on the non-pressure (stabbing) flank.
b. Burrs and other protrusions on the pin chamfer and starting
thread
may also be removed, when approved by the customer. c. The
starting thread and first two (2) full crested threads of the
pin
and box are less critical than the other threads. Normal flank
and crest wear is allowable but there should not be any type of
thread form distortion that would cause thread damage during
make-up.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 11 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
d. A thread profile gauge is a valuable tool for identifying an
acceptable
thread form. If the entire length of the gauge will not seat
snugly in the threads, starting in the first full crested thread
from the shoulder, look for a high spot or protrusion (on one [1]
or more thread surfaces) or for pin stretch. If the gauge seats
loosely on the threads, flank wear or flank corrosion may be
excessive. To ensure proper repair, verify that the gauge seats
correctly over the repair area.
5.5.3 Bevel. Verify that there is an approximate 45 bevel from
the shoulder to
the tool joint O.D. which has a minimum width of 1/32 inch (0,79
mm). This bevel must extend the full 360 circumference of the tool
joint on both pin and box ends.
5.5.4 Box Outside Diameter Swell (Tool Joints only). Place a
straight edge
(steel rule) along the longitudinal axis of the outside of the
connection, looking for a gap between the straight edge and the
connection.
NOTE: This is not a requirement of API RP 7G, but may be used as
a quick
visual check only. Acceptance shall be based on box counterbore
diameter, see 5.6.8.
5.5.5 Box Diameter Swell (Drill Collars and BHA Components only.
Place a
straight edge (steel rule) along the longitudinal axis of the
box threads, looking for rocking due to swelling of the box.
5.5.6 Shoulder Flatness. Place a straight edge across the
diameter of the box
shoulder, rotating the straightedge through 180 look for any
gaps between the shoulder and straightedge. Repeat the process for
the pin by placing the straightedge across the largest chord of the
pin possible. Any gap noticed shall be cause for rejection or
marked for shop repair or refacing, if requested by the
customer.
5.5.7 Thread Profile. Check the pin threads for stretch by
placing the profile
gauge across the interval which includes the first full-depth
thread nearest the shoulder. Check in two (2) positions, 90 apart.
Any condition where the profile gauge will not sit squarely in the
thread form shall be evaluated with a lead gauge in accordance with
5.6.10.
5.5.8 Hard-banding. Check the condition of the hard-banding when
present.
Broken and missing areas shall be reported to the customer.
Hairline
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SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 12 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
cracks are permissible provided the cracks do not extend into
the base metal. Protruding carbide chips or beads shall be
rejected, unless permitted by the customer.
5.6 Tool Joint Dimensional Measurements (Refer to Figure 1.2 -
a)
5.6.1 Outside Diameter (Item E).
a. Establish the acceptable tool joint wear in accordance with
7.1 or customer specifications, as applicable.
b. Set the caliper to the minimum OD for tool joint size being
calipered by
adjusting the caliper contacts using the steel rule. c. Caliper
each tool joint, approximately 1 inch (2,5 cm) from the
shoulder, 360 of the OD surface. If caliper goes over at any
point, it is not a premium tool joint, proceed to 5.6.1.d.
d. Locate minimum OD and set caliper to the reduced tool joint
OD.
Take a measurement of caliper opening by placing one (1) of the
contacts at the end of the steel rule representing 0" and read to
the nearest 1/32 inch (0,8 mm), classify to the applicable criteria
referenced in 7.1.
e. Repeat 5.6.1.a for each tool joint.
5.6.2 Pin Inside Diameter (Item A). Using the internal spring
caliper, measure
the internal diameter of the pin under the last thread nearest
the shoulder. Place one (1) of the contacts at the end of the steel
rule representing 0" and read the diameter to the nearest 1/32 inch
(0,8 mm).
5.6.3 Bevel Diameter (Item B). Measure the bevel diameter of the
box
connection with the steel rule to the nearest 1/64 inch. For the
pin end, adjust the external spring caliper to the bevel diameter,
place one (1) of the contacts at the end of the rule representing
0" and read the diameter to the nearest 1/64 inch (0,5 mm).
5.6.4 Tong Space (Item C). Measure the available tong space on
both pin and
box connections, excluding the bevel. Tong space measurements on
hard-banded boxes shall not include the length of the hard-banding.
In cases where the hard-banding has been worn flat (essentially the
same
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 13 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
diameter as the tool joint), the hard-banded area may be
included in the tong space measurement, but shall be
documented.
5.6.5 Box Shoulder Width (Item F). Using the steel rule, measure
the width of
the shoulder, including bevels, at the narrowest point, to the
nearest 1/64 inch (0,5 mm).
5.6.6 Pin Neck Length (Item I). Using the steel rule, measure
the width of the
pin neck length, at the intersection of the flank of the first
full depth thread. Pin neck length shall not exceed 9/16 inch (14
mm).
5.6.7 Box Seal Width (Item G). Using the steel rule, measure the
width of the
seal, at the narrowest point, to the nearest 1/64 inch (0,5 mm).
5.6.8 Box Counterbore Diameter (Swell) (Item H). Using a steel
rule, dial or
vernier caliper, set the I.D. caliper 1/16 inch (1,5 mm) above
the QC dimension specified in Table 25 of API Spec 7. Check each
box with the calipers. If the calipers slip inside the box at any
point, the counterbore has exceeded the nominal diameter by more
than 1/16 inch (1,5 mm) and the tool joint must be identified as
shop repairable or scrap.
5.6.9 Box Counterbore Depth (Item J). Measure the depth of the
box
counterbore, to the nearest 1/64 inch (0,5 mm), from the make-up
shoulder to the intersection of the first point of thread taper
inside the box connection.
5.6.10 Pin Lead. Using the profile gauge, check for damaged
thread form
throughout the connection which would interfere with proper
make-up. Ensure the lead gauge has the proper diameter contact
points for the thread form being inspected in accordance with
3.7.3.
a. Lead Gauge Standardization. The accuracy of the gauge is
verified
by applying the gauge to the lead setting standard. With both
contacts in a setting standard groove, the gauge should be pivoted
in an arc about the fixed contact. Adjustment is necessary if the
gauge does not register zero. This adjustment is made by loosening
the lock screw on the arm adjusting the gauge to read zero by
adjusting the screw and then re-tightening the lock screw.
b. With the gauge set for a 2 inch interval measure the lead
across the
last engaged thread. The gauge is pivoted on the fixed contact
point
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SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 14 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
through a small arc. The reading from zero is the lead error.
Two (2) measurements 90 apart are required. If the reading exceeds
0.006 inches, the connection shall be marked for re-cut.
NOTE: Do not take measurement where thread flank damage exists.
5.7 Drill Collars and BHA Components (Refer to Figure 1.2 - b)
5.7.1 Box Outside Diameter (Item E). For drill collars and other
components of
the BHA, measure the diameter of the box connection
approximately 4 inches (10 cm) from the shoulder. Place one (1) of
the contacts at the end of the steel rule representing 0" and read
the diameter to the nearest 1/32 inch (0,8 mm). Two (2)
measurements shall be made approximately 90 apart.
5.7.2 Pin Inside Diameter (Item A). For the pin of drill collars
or other
components of the BHA assembly, measure the internal diameter
under the last thread nearest the shoulder using the internal
spring caliper. Place one (1) of the contacts at the end of the
steel rule representing 0" and read the diameter to the nearest
1/32 inch (0,8 mm).
5.7.3 Pin Length (Item D). Measure the length of the pin to the
nearest 1/64
inch (0,5 mm).
5.7.4 Pin Relief Groove Diameter (Item B). For those connections
with the relief groove feature on the pin end, the diameter of the
groove shall be measured to the nearest 1/64 inch (0,5 mm) at the
mid point of the relief groove using an external caliper.
5.7.5 Pin Relief Groove Width (Item C). For those pin
connections with a
stress relief groove, use a steel rule and measure its width at
the intersection of the load flank and crest of the first
full-depth thread from the shoulder.
5.7.6 Box Counterbore Diameter (Swell) (Item G). Using a steel
rule, dial or
vernier caliper, set the I.D. caliper 1/16 inch (1,5 mm) above
the QC dimension specified in Table 25 of API Spec 7. Check each
box with the calipers. If the calipers slip inside the box at any
point, the counterbore has exceeded the nominal diameter by more
than 1/16 inch (1,5 mm) and the tool joint must be identified as
shop repairable or scrap.
5.7.7 Boreback Diameter (Item F). For those connections with a
bore back
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 15 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
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Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
relief feature on the box end, the diameter of the cylinder
shall be measured to the nearest 1/64 inch (0,5 mm) at the mid
point of the cylinder using an internal caliper and steel rule.
5.7.8 Boreback Length (Item I). For those connections with a
bore back relief
feature on the box end, the length of the boreback shall be
measured with a steel rule.
5.7.9 Box Counterbore Depth (Item J). Measure the depth of the
box
counterbore to the nearest 1/64 inch (0,5 mm) measured from the
make-up shoulder to the intersection of the first point of thread
taper inside the box connection.
5.7.10 Boreback Thread Length (Item K). For those connections
with a bore
back relief feature on the box end, the length of the box
threads shall be measured with a steel rule measured from the
make-up shoulder to the last point of full thread depth.
5.7.11 Pin Neck Length (Item I, Figure 1.2 - a). For pin
connection without
stress relief grooves, use a steel rule and measure the width of
the pin neck length, at the intersection of the flank of the first
full depth thread. Pin neck length shall not exceed the counterbore
depth minus 1/16 inch (1,5 mm).
5.7.12 Mid Tube Upset Diameter of HWDP. For HWDP with a mid tube
upset,
the diameter of the upset shall be measured at the center. Using
the external caliper, adjust the caliper to the outside diameter of
the mid-tube upset on HWDP. Use the steel rule to determine the
diameter to the nearest 1/64 inch (0,5 mm). Two (2) measurements
are required, approximately 90 apart.
NOTE: The measurements shall be taken adjacent to rather than
over any
applied hard-banding. 5.7.13 Mid Tube Upset Height of HWDP. For
HWDP with a mid tube upset, the
height of the upset in relation to the tube body shall also be
measured. The difference between the maximum height and the minimum
height shall be less than or equal to 1/8 inch (3 mm). The diameter
of the upset shall comply with the requirements in Table
5.7.13.
NOTE: Two (2) measurements on each connection are required,
approximately 90 apart.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 16 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
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Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
5.7.14 In addition to the above, refer to applicable items from
5.6 for required
dimensional checks for BHA connections as specified by Table
1.2. 5.8 Tube Body Inspections
5.8.1 Visual. Visually examine both the inside and outside
surfaces of the pipe body for obvious damage. Particular attention
shall be paid to the critical and slip areas. The internal upset
area shall also be carefully examined for pitting using a light and
mirror. The pipe shall be rotated through a minimum of 1-1/4
revolutions to facilitate full inspection.
a. The internal surface of internally coated drill pipe shall be
inspected
for signs of deterioration of the coating using a light and
mirror. If such conditions exist, the customer shall be
notified.
5.8.2 Straightness. Rotate the pipe a minimum of two (2)
complete revolutions
while observing straightness of the tube body. Lengths obviously
bowed, bent or corkscrewed shall be classified as rejects or
straightened in accordance with the Tuboscope Divisional Operating
Procedures for straightening.
5.9 O.D. Gauging. The tube body outside diameter shall be
mechanically gauged from
upset to upset to determine abrasive wear and/or mechanical
damage using an OD gauge or spring caliper. The pipe is rolled as
the OD gauge or caliper is dragged or stabbed along the
surface.
5.9.1 Surface Condition. The outside diameter of the tube must
be free of
scale, mud, etc. Clean as necessary to adequately perform the OD
gauging.
5.9.2 Standardization.
a. Standardize the OD gauge by placing the setting standard
between
the fixed and moveable contacts. Check and adjust the anvils, if
necessary, so the anvils are parallel and the setting standard fits
snug at both ends of the anvil and at an exact gauge bar distance
apart at each corner. Ensure that all screws are tight. Adjust the
wire indicator to point to the number 1 (for 1/32 inch).
b. Standardization Checks. Verify that the setting standard
still fits as
described in 5.9.2.a at the following intervals. All pipe
inspected
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 17 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
between an unacceptable check and the most recent acceptable
check shall be reinspected.
1. At the beginning and end of each inspection shift and after
meal
break. 2. At least once every hour of continuous operation or
every 25
pipe inspected. 3. Whenever there is a change in inspector. 4.
When the OD gauge is subjected to abnormal mechanical shock. 5.
Prior to resuming operation after repair or adjustments. 6. If any
looseness of the movable face is detected. 7. Whenever in doubt of
the accuracy of the gauge.
5.9.3 Each length of pipe shall be OD gauged full length (upset
to upset). The
pipe is rolled a full 360. Ensure that the anvils of the OD
gauge stay tight during the job.
5.9.4 While the length is rolling on the pipe rack, push the
gauge firmly against
the length and drag the gauge laterally along the entire length.
a. The gauge makes a continuous spiral track down the length.
Distance
gauged during one (1) revolution is approximately one (1) foot.
b. Allow the length to roll as many complete revolutions as
necessary to
gauge the pipe from upset to upset. c. At any section where the
length is worn more than 1/32 inch (0,79 mm),
the gauge will slip over the length completely. 5.9.5 Circle the
pipe with chalk or marking crayon and calculate percent of OD
wear at point on the pipe where maximum wear was found during
gauging. Determine the minimum wall thickness in accordance with
6.2 in SOP III-403.
NOTE: Calculated Wear = Maximum wear reading minus 1/2 the
minimum wear
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 18 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
reading multiplied by the wall percent for pipe being
inspected.
Example: 4- in., 0.337 in. wall thickness, 1/32 in. of specified
wall = 9.3%, gauge readings: Max 2, Min 1 1/2 of 1 = 0.5, 2 - 0.5 =
1.5 X 9.3% = 14%
5.9.6 Slip/Critical Area Gauging a. Place the gauge over the
pipe in the slip/critical area with the center
wear block firmly against the pipe surface. b. Read the gauge
while rotating the length and moving the gauge
laterally through the slip/critical area. c. If a reduction, as
indicted by the gauge indicator, is close to down-
grading as per the applicable Table 7.2.3 1 through 7.2.3 - 18
in SOP III-002 or applicable customer specification or if
mechanical damage is evident, use OD calipers and measure exact OD
to determine the classification.
5.9.7 Measuring Mechanical Damage a. Diameter Variations 1.
Dents, Mashes, Stretch and Necking. Caliper and measure.
Record, in percentage, the OD reduction in the Percent OD Wear
column of the Drill Pipe Inspection Report.
2. String shot. Caliper and measure. Record, in percentage, the
OD
increase in the Percent OD Wear column of the Drill Pipe
Inspection Report.
6.0 FIELD REFACING OF USED TOOL JOINT SHOULDERS
6.1 Bench Mark. A benchmark is used to aid in determining if
shoulder face damage should be repaired by field refacing. The
bench marks may be in the form of one (1) of the following:
6.1.1 A short transverse line or tangent at the base of a symbol
stamped on
the base of the pin shoulder or on the box counterbore. 6.1.2 A
transverse groove machined into the shoulder face of the pin.
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SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 19 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
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Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
6.1.3 A transverse ridge machined on the base of the pin
shoulder or the box counterbore.
6.2 When the tool joint is new, the bench mark is placed a
specific distance from the shoulder face. Usually 1/8 inch, but
will vary according to the tool joint manufacturer.
6.3 During use and periodic refacing, the distance from the
shoulder face to the
bench mark changes. When the original (manufacturer) distance is
changed by 1/16 inch (1,5 mm)or less by field repair of the
shoulder face, then the tool joint is considered safe for use. If
the original (manufacturer) distance to the face is changed by more
than 1/16 inch (1,5 mm), the tool joint cannot be refaced and shall
be painted red to be shop repaired (re-cut) or scrapped.
6.3.1 When refacing, a minimum amount of material should be
removed and <
1/32 inch (0,8 mm) at any one (1) refacing. Cumulatively, # 1/16
inch (1,5 mm).
6.4 Shoulder Face Bevel. 6.4.1 After or during the refacing
operation, a 45 bevel diameter shall be cut
on the outer edge of the shoulder face. The bevel must extend
the full 360 circumference. Never cut more than a 3/32 inch (2 mm)
bevel.
6.4.2 For API RP7G inspections, never allow the shoulder width
to be < the
value in Table 10 in API RP7G, for the type and class of tool
joint being beveled.
a. On worn tool joints, it may not be possible to cut the
original bevel
diameter because of a lack of shoulder width. In this case,
scrap the connection.
NOTE: API RP7G and DS-1 define the term shoulder differently.
See Figure 1.2-
a, items F and G. 6.4.3 For DS-1 inspections, never allow the
seal width to be < the value in the
applicable Table 3.7.1, 3.7.9 or 3.9.1 in DS-1, for the type and
class of tool joint being beveled.
a. On worn tool joints, it may not be possible to cut the
original bevel
diameter because of a lack of seal width. In this case, scrap
the
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 20 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
connection. 6.4.4 On eccentric worn tool joints, it may not be
possible to cut the original
bevel at the area of eccentric wear. In this case, scrap the
connection. 6.5 Coating of Shoulder Face. After a shoulder seal has
been refaced by
machining, a copper sulfate coating should be applied to the
face, if specified by the customer. This will prevent seizing and
galling, during "break in" of the new face, when the tool joint is
"made up" and "broke out" on the rig floor.
6.5.1 The coating should be mixed up on a per job basis. 6.5.2
Mix three (3) tablespoons crushed (powdered) copper sulfate with
three
(3) tablespoons sulfuric acid. Mix well. 6.5.3 Pour the above
acid solution into one (1) quart of water, NEVER pour
water into acid! Mix well. 6.5.4 Once experience shows how many
faces can be done per quart, larger
quantities can be mixed as the job size requires. 6.5.5 Apply
the copper sulfate solution to the clean face of the tool joint
with a
plastic bristled brush. Use rubber gloves when mixing and
applying the solution sulfuric acid will burn the skin.
7.0 CLASSIFICATION OF TOOL JOINTS AND ROTARY SHOULDERED
CONNECTIONS
7.1 Tool Joints. Tool joints shall be classified as Premium or
Class 2 in accordance with Table 10 of API RP 7G, Table 3.7.1
through 3.7.11 in DS-1, or Table 6, 6a, 6b or 6c in NS-2, as
applicable.
7.1.1 For Dimensional 1 or 2 Acceptance Criteria not listed in
Table 10 and
Section 12 of API RP 7G, refer to Table 3.7.1 through 3.7.7 in
DS-1, as applicable.
7.2 Drill Collars. For Drill Collar Acceptance Criteria refer to
Table 3.8 in DS-1 or
Table 9 in NS-2, as applicable.
7.3 HWDP. For HWDP Acceptance Criteria refer to Table 3.9.1
through 3.9.6 in DS-1 or Table 8 in NS-2, as applicable.
7.4 Shoulders. Shoulders shall be classified as follows:
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 21 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
7.4.1 Acceptable. No repair work is required. 7.4.2 Repairable.
This applies to field or shop repairable. 7.4.3 Non-repairable.
Scrap. 8.0 POST INSPECTION PROCEDURES
The applicable requirements of Sections 15.0 and 18.0 in SOP
III-001 shall be followed when the last inspection service is
completed on each piece.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 22 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
Table 1.2 - Dimensional and Visual Inspection Attributes
API RP 7G Dimensional / Visual Attribute Required Optional
Dimensional1
Dimensional 2
Dimensional 3
5.5.1 - Shoulder (Face) X X X X 5.5.2 - Visual Thread Inspection
X X X X 5.5.3 Bevel Width/Angle X X X X 5.5.4 & 5.5.5 - Box
Counterbore Diameter (Swell) - Visual X X X
5.5.6 - Shoulder Flatness X X 5.5.7 - Thread Profile X X X X
5.5.8 Hardbanding X X X 5.6.1 & 5.7.1 - Outside Diameter X X X
X 5.6.2 & 5.7.2 - Pin Inside Diameter X X X 5.6.3 - Bevel
Diameter X X 5.6.4 - Tong Space X X X 5.6.5 - Box Shoulder Width X
X X X 5.6.6 & 5.7.11 - Pin Neck Length (Pin Flat) X X
1
5.6.7 - Box Seal Width X X 5.6.8 & 5.7.6 - Box Counterbore
Diameter (Swell) Measurement X X X X
5.6.9 & 5.7.9 - Box Counterbore Depth X X 5.6.10 - Pin Lead
X X2 X2 X2 5.7.3 - Pin Length X 5.7.4 - Pin Relief Groove Diameter
X 5.7.5 - Pin Relief Groove Width X 5.7.7 - Boreback Diameter X
5.7.8 - Boreback Length X 5.7.10 - Boreback Thread Length X 5.7.12
- Center Upset Dia. on HWDP X 5.7.13 - Center Upset Height on HWDP
X
NOTE: When an API RP 7G Optional inspection is specified by the
customer, all items listed under Required and Optional must be
performed. 1 - Not applicable to connections containing a stress
relief groove. 2 Only required when the profile gauge indicates pin
stretch.
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 23 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
E B
F
G
H
E - OUTSIDE DIAMETER (BOTH PIN AND BOX)
BOX:
F - BOX SHOULDER WIDTH (DS-1)G - BOX SEAL WIDTH (DS-1) (Box
Shoulder Width per API RP7G)H - BOX COUNTERBORE DIAMETER
C
A
B
C
D
B - BEVEL DIAMETER (BOTH PIN AND BOX)
PIN:
C - TONG SPACE (BOTH PIN AND BOX)D - BEVEL WIDTH
A - PIN INSIDE DIAMETER
I
I - PIN NECK LENGTH (PIN FLAT)
LPC
LBT
J
J - BOX COUNTERBORE DEPTH Figure 1.2-a
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 24 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
I
J
K
HG
E
FD
C
A
B
LEGEND:
E - BOX OUTSIDE DIAMETERB - PIN RELIEF GROOVE DIAMETER
PIN:
C - PIN RELIEF GROOVE WIDTHD - PIN LENGTH
BOX:
A - PIN INSIDE DIAMETERF - BOREBACK DIAMETER
H - BEVEL DIAMETER (PIN AND BOX)G - BOX COUNTERBORE DIAMETER
I - BOREBACK LENGTHJ - BOX COUNTERBORE DEPTH
K - BOREBACK THREAD LENGTH
Figure 1.2-b
Table 3.7.3 - Gauge Contact Point Diameter (Inches) Thread
Type
Connection Number Style
Diameter
V-0.038 R NC 0.142 - 0.146 V-0.040 R REG (2-3/8 to 4-1/2) 0.113
- 0.117 V-0.050 REG (5-1/2 to 8-5/8) and FH 0.142 - 0.146
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 25 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
Figure 5.3.2 1 - Old API Marking System for Drill Pipe
Figure 5.3.2 2 - New API Marking System for Standard Wall Drill
Pipe
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 26 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
Dimensional Inspection
Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
Figure 5.3.2 3 - New API Marking System for Heavy Wall Drill
Pipe
Figure 5.3.2 4 - New API Marking System for Thick Wall Drill
Pipe
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 27 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
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Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
Example: Grant Prideco Tool Joint joined April, 2001 on US Steel
Grade X Drill Pipe
Figure 5.3.2 5 Weight/Grade Codes and API Pin Neck Marking
System
Pipe Size (in.)
Weight (lb./ft.)
Weight Code
2-3/8 4.85 6.65 Std 1 2
2-7/8 6.85 10.40 Std 1 2
3-1/2 9.50
13.30 Std 15.50
1 2 3
4 11.85
14.00 Std 15.70
1 2 3
4-1/2
13.75 16.60 Std
20.00 22.82 24.66 25.50
1 2 3 4 5 6
5 16.25
19.50 Std 25.60
1 2 3
5-1/2 19.20 21.90 24.70
1 2 3
5-7/8 23.40 26.30 2 3
6-5/8 25.20 Std 27.70 2 3
Grade Grade Code E75 E X95 X G105 G S135 S Z140 Z V150 V
Mill/Processor SymbolAlgoma X British Steel B Dalmine D Grant
Prideco GP Kawasaki H Nippon I NKK K Mannesmann M Omsco OMS
Reynolds Aluminum RA Sumitomo S Siderca SD Tamsa T US Steel N
Vallorec V
GP 401 N X1 2 3 4
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Effective Date August 1, 2005
SOP No. III-100
VOLUME III USED DRILL PIPE Revision No. 0 Page No. 28 of 28
STANDARD OPERATING PROCEDURE (Company Confidential) Visual and
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Copyright 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001
Table 5.7.13 - Heavy Weight Drill Pipe Center Upset
Dimensions
Pipe Size Minimum Center Pad Diameter
3-1/2 3-7/8 4 4-13/32
4-1/2 4-31/32 5 5-3/8
5-1/2 5-7/8 6-5/8 7