SOP III-100 R00

VOLUME III – USED DRILL PIPE STANDARD OPERATING PROCEDURE (Company Confidential)

Effective Date August 1, 2005

SOP No. III-100

Revision No. 0

Page No. 1 of 28

Visual and Dimensional Inspection

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

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

VOLUME III – USED DRILL PIPE STANDARD OPERATING PROCEDURE (Company Confidential)

Effective Date August 1, 2005

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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, DS1 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.

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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TABLE OF CONTENTS 1.0 2.0 3.0

4.0 5.0

Scope............................................................................................................................................ 5 1.2.1 Tool Joints ........................................................................................................5 1.2.3 BHA..................................................................................................................5 Personnel Requirements.............................................................................................................. 6 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 Surface Preparation...................................................................................................................... 8 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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

VOLUME III – USED DRILL PIPE STANDARD OPERATING PROCEDURE (Company Confidential)

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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. Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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.

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

3.4

Electronic, dial or vernier type calipers may also be used for measuring purposes.

A small, flat, non-tinted mirror for observing the load flanks and roots of the internal threads. Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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appropriate for the thread pitch and thread taper. 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

4.0

Effective Date August 1, 2005

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.

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.

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.

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

VOLUME III – USED DRILL PIPE STANDARD OPERATING PROCEDURE (Company Confidential)

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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 manufacturer’s 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. Manufacturer’s 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 manufacturer’s 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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 III001. 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 makeup 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. Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 makeup 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 midtube 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. Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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

5.9

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.

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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 III403.

NOTE: Calculated Wear = Maximum wear reading minus 1/2 the minimum wear Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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reading multiplied by the wall percent for pipe being inspected. Example: 4-½ 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 downgrading 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 6.1.2

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. A transverse groove machined into the shoulder face of the pin. Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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6.1.3

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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

6.4

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).

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 1.2a, 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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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connection. 6.4.4

6.5

7.0

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. 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.

CLASSIFICATION CONNECTIONS 7.1

OF

TOOL

JOINTS

AND

ROTARY

SHOULDERED

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 DS1 or Table 8 in NS-2, as applicable.

7.4

Shoulders. Shoulders shall be classified as follows: Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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.

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.

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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Table 1.2 - Dimensional and Visual Inspection Attributes API RP 7G Dimensional / Visual Attribute 5.5.1 - Shoulder (Face) 5.5.2 - Visual Thread Inspection 5.5.3 – Bevel Width/Angle 5.5.4 & 5.5.5 - Box Counterbore Diameter (Swell) - Visual 5.5.6 - Shoulder Flatness 5.5.7 - Thread Profile 5.5.8 – Hardbanding 5.6.1 & 5.7.1 - Outside Diameter 5.6.2 & 5.7.2 - Pin Inside Diameter 5.6.3 - Bevel Diameter 5.6.4 - Tong Space 5.6.5 - Box Shoulder Width 5.6.6 & 5.7.11 - Pin Neck Length (Pin Flat) 5.6.7 - Box Seal Width 5.6.8 & 5.7.6 - Box Counterbore Diameter (Swell) – Measurement 5.6.9 & 5.7.9 - Box Counterbore Depth 5.6.10 - Pin Lead 5.7.3 - Pin Length 5.7.4 - Pin Relief Groove Diameter 5.7.5 - Pin Relief Groove Width 5.7.7 - Boreback Diameter 5.7.8 - Boreback Length 5.7.10 - Boreback Thread Length 5.7.12 - Center Upset Dia. on HWDP 5.7.13 - Center Upset Height on HWDP

Required Optional X X X

Dimensional Dimensional 1 2 X X X

X X X

X X X

X

X

X

X X X X X X X X

X X X X X X

X

X1

X

X

X

X X X X

X X

X X

X

Dimensional 3

X

X

X

X

X

X

X2

X X2

X X2 X X X X X X X 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.

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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C

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LPC

B

D A

PIN: A - PIN INSIDE DIAMETER B - BEVEL DIAMETER (BOTH PIN AND BOX) C - TONG SPACE (BOTH PIN AND BOX) D - BEVEL WIDTH I - PIN NECK LENGTH (PIN FLAT)

I

C

E BH G J F

LBT

BOX: E - OUTSIDE DIAMETER (BOTH PIN AND BOX) F - BOX SHOULDER WIDTH (DS-1) G - BOX SEAL WIDTH (DS-1) (Box Shoulder Width per API RP7G) H - BOX COUNTERBORE DIAMETER J - BOX COUNTERBORE DEPTH Figure 1.2-a Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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H G J

K B

C I E

A

D F

LEGEND: PIN:

BOX:

A - PIN INSIDE DIAMETER B - PIN RELIEF GROOVE DIAMETER

E - BOX OUTSIDE DIAMETER

C - PIN RELIEF GROOVE WIDTH

F - BOREBACK DIAMETER G - BOX COUNTERBORE DIAMETER

D - PIN LENGTH

H - BEVEL DIAMETER (PIN AND BOX) I - BOREBACK LENGTH J - BOX COUNTERBORE DEPTH K - BOREBACK THREAD LENGTH

Figure 1.2-b Table 3.7.3 - Gauge Contact Point Diameter (Inches) Thread Connection Diameter Type Number Style 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

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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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 Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

VOLUME III – USED DRILL PIPE STANDARD OPERATING PROCEDURE (Company Confidential)

Pipe Size (in.) 2-3/8 2-7/8 3-1/2 4

4-1/2

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

Weight (lb./ft.) 4.85 6.65 Std 6.85 10.40 Std 9.50 13.30 Std 15.50 11.85 14.00 Std 15.70 13.75 16.60 Std 20.00 22.82 24.66 25.50 16.25 19.50 Std 25.60 19.20 21.90 24.70 23.40 26.30 25.20 Std 27.70

Weight Code 1 2 1 2 1 2 3 1 2 3 1 2 3 4 5 6 1 2 3 1 2 3 2 3 2 3

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Grade Code E75 E X95 X G105 G S135 S Z140 Z V150 V Mill/Processor Symbol Algoma 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 Grade

1 2 34 GP 401 N X

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

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001

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Table 5.7.13 - Heavy Weight Drill Pipe Center Upset Dimensions Pipe Minimum Center Pad Diameter Size 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

Copyright © 2005 Tuboscope, P.O. Box 808, Houston, Texas 77001