sop iii-001 r00

Effective Date August 1, 2005

SOP No. III-001

VOLUME III USED DRILL PIPE Revision 0 Page No. 1 of 27

STANDARD OPERATING PROCEDURE

(Company Confidential) General Requirements

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

GENERAL REQUIREMENTS


FOR USED DRILL PIPE 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


SOP No. III-001





INTRODUCTION The intent of this document is to serve as a general operating guide for all used drill pipe inspection services performed in accordance with this Standard Operating Procedure Manual, Volume III. Each standard operating procedure contained in this manual will refer to this procedure for like requirements such as; Reference Documentation, General Definitions, General Personnel Requirements, General Equipment Requirements, General Pipe Cleaning and Preparation, Identification of Material, Customer Notification, Post Inspection Procedures, Equipment Calibration / Verification Frequencies.


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TABLE OF CONTENTS 1.0 Scope............................................................................................................................................ 4 2.0 Reference Documents.................................................................................................................. 4 3.0 Definitions ..................................................................................................................................... 6 4.0 Personnel Requirements and Training ........................................................................................ 7 5.0 Radiation Requirements............................................................................................................... 8 6.0 Accident Control and Safety......................................................................................................... 9 7.0 Planning the Inspection ................................................................................................................ 9 8.0 Inspection Equipment Condition .................................................................................................. 9 9.0 Equipment Requirements............................................................................................................. 9 9.1 Equipment Calibration........................................................................................................ 9 9.2 Visible Light Requirements .............................................................................................. 10 9.3 Black Light (UV-A) Sources ........................................................................................10 9.4 Facility Requirements....................................................................................................... 11 9.6 Tuboscope EMI Buggy Reference Standards ................................................................. 12 9.6.1 Eight (8) Hole Flux Leakage Standards ............................................................. 12 9.6.2 Wall Thickness Standard.................................................................................... 13 9.7 Endsonic Reference Standards ....................................................................................... 13 9.7.4 Notches ............................................................................................................... 14 9.7.7 Wall Reduction.................................................................................................... 15 10.0 Material Condition....................................................................................................................... 15 10.1.1 Scale ................................................................................................................... 15 10.1.2 Excessive Pitting................................................................................................. 16 11.0 Identification of Material ............................................................................................................ 16 12.0 Customer Notifications .............................................................................................................. 17 13.0 Removal of Thread Protectors ................................................................................................... 18 14.0 Inspection Surface Preparation.................................................................................................. 18 15.0 Reinstallation of Thread Protectors............................................................................................ 19 16.0 Evaluation of Imperfections 20 17.0 Acceptance Criteria .................................................................................................................... 20 18.0 Post Inspection Procedures ....................................................................................................... 20 18.1 Drill Pipe Inspection Classification ................................................................................... 20 18.2 Inspection Classification Markings................................................................................... 21 18.2.3 Tool Joints......................................................................................................21 18.3 Bottom Hole Assembly (BHA) Inspection Classification ............................................... 22 18.5 Pipe Segregation.............................................................................................................. 22 18.6 Inspection Records........................................................................................................... 23 Figure 3.3 Slip/Critical Areas ............................................................................................................. 24 Table 9.1 - Equipment Verification / Calibration Frequency .............................................................. 25 Table 11.3 - Permanent Marking Locations........................................................................................ 26 Figure 14.1............................................................................................................................................ 26 Figure 18.2.1......................................................................................................................................... 27 Table 18.2.3 - Tool Joint and BHA Classification Markings............................................................... 27


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1.0 SCOPE 1.1 This procedure establishes minimum general requirements related to inspection

personnel and equipment, identification of material, material handling, customer notification, imperfection evaluation, acceptance criteria and post inspection requirements for inspection of used drill pipe, drill collars, heavy weight and bottom hole assemblies.

1.2 Tuboscope document is the controlling document whenever any other like kind

prior-dated Tuboscope inspection procedures are in conflict. 1.3 This procedure shall be used in conjunction with all other applicable procedures

in this manual for each inspection technique/method applied to the material identified in 1.1.

1.4 Tuboscope inspection personnel shall perform the required activities in

accordance with the procedures contained in this manual. In cases of conflict between the procedures contained in this manual, and applicable customer specifications, the customer specifications shall govern.

2.0 REFERENCE DOCUMENTS 2.1 Current API Publications containing dimensional tables and methods of inspection

for the grade of pipe to be inspected must be available for reference. Effective December 14, 1992 Tuboscope Vetco International Inc. was given permission by the American Petroleum Institute to reproduce with acknowledgement portions of current API Publications. Relevant sections of each API edition may be copied pertaining to the pipe being inspected. Copies must include the publications cover and the relevant sections "rubber stamped" with the words (COPIED BY PERMISSION OF AMERICAN PETROLEUM INSTITUTE). It is now permissible by the Quality and Technical Services Department to have only portions of relevant sections of API documents of each unit. In addition, all documents published by Tuboscope, A Varco Company which provide detailed standardization, operation, and/or maintenance guidelines for a full length tubular inspection system or any other required inspection equipment pertaining to the services provided must be available on the job site and reviewed periodically by the Operator or Inspector.

2.2 This manual contains data (based on information contained in the American

Petroleum Institute Standards and Recommended Practices and the American Society for Testing and Materials Standards in effect as of August 1, 2005), magnetization current requirements, hardness values, fraction/decimal


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equivalents, ultrasonic formulas and other data frequently used by Tuboscope. TUBOSCOPE BELIEVES THAT THE INFORMATION CONTAINED IN THIS

MANUAL HAS BEEN OBTAINED FROM RELIABLE SOURCES, AND IS CORRECT AND ACCURATE; HOWEVER, THE INFORMATION IS PROVIDED AS IS AND TUBOSCOPE MAKES NO GUARANTEE, REPRESENTATION, OR WARRANTY, EXPRESS OR IMPLIED, REGARDING THE DATA AND INFORMATION CONTAINED IN THIS DOCUMENT, OR THE COMPLETENESS, ACCURACY, OR SUITABILITY OF SUCH INFORMATION FOR ANY PARTICULAR PURPOSE OR USE, AND ALL WARRANTIES, INCLUDING ANY AND ALL WARRANTIES OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, ARE EXPRESSLY DISCLAIMED.

2.3 All documents referenced in this procedure shall be maintained to the latest

revision. 2.4 The latest revision of the following documents were used as references for

establishing this procedure:

2.4.1 A.S.N.T. Recommended Practice SNT-TC-1A - Personnel Qualification and Certification in Nondestructive Testing.

2.4.2 CAN/C.G.S.B. - 48.9712 - Nondestructive Testing - Qualification and

Certification of Personnel. 2.4.3 A.P.I. Specification 7 Specification for Rotary Drill Stem Elements.

2.4.4 A.P.I. Recommended Practice 5A5 - Field Inspection of New Casing,

Tubing and Plain End Drill Pipe. 2.4.5 A.P.I. Recommended Practice 7G Recommended Practice for Drill

Stem Design and Operating Limits. 2.4.6 A.P.I. Recommended Practice 7A1 Recommended Practice for Testing

of Thread Compounds for Rotary Shouldered Connections.

2.4.7 A.P.I. Standard 5T1 - Imperfection Terminology. 2.4.8 A.S.T.M. E 1316 - Standard Terminology for Nondestructive

Examinations.

2.4.9 A.S.T.M. E 2297 - Standard Guide for Use of UV-A and Visible Light Sources and Meters used in the Liquid Penetrant and Magnetic Particle


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Methods. 2.4.10 I.E.E.E./A.S.T.M. SI 10 - Standard for Use of the International System of

Units (SI): The Modern Metric System. 2.4.11 Standard DS-1 Drill Stem Design and Inspection.

2.4.12 NS-2 North Sea Drillstring Inspection Standard. 2.4.13 SOP III-002 - Evaluation of Pipe Body Imperfections.

2.4.14 SOP III-100 - Visual and Dimensional Inspection. 2.4.15 SOP 307 - Procedures for Emergencies That Involve Radioactive Material. 2.4.16 SOP 309 - Routine Radiation Procedures. 2.4.17 Tuboscope Qualification/Certification Manual, Section 1 - Written

Practice. 2.4.18 Tuboscope QTS Bulletin #1-94 - Calibration Check Methods for

Inspection, Measuring and Testing Equipment. 2.4.19 Tuboscope QTS Bulletin #1-95 ASTM E317 Certification of UT Flaw

Scope.

2.4.20 Tuboscope Inspection Equipment Calibration Procedures. 2.4.21 Quality System Procedure, QSP-42-02 Control of Records.

2.4.22 Quality System Procedure, QSP-76-01 - Inspection, Measuring and Test

Equipment. 3.0 DEFINITIONS Within this and other Tuboscope Standard Operating Procedures (SOPs) contained in

this manual, the following definitions shall apply: 3.1 Calibration. The comparison of an instrument with, or the adjustment of an

instrument to, a known reference(s) often traceable to the National Institute of Standards and Technology (N.I.S.T.). A.S.T.M. E1316.

3.2 Marking. The term "marking" is this procedure to include inspection markings that


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are made with paint stencils, paint sticks, and ballpoint paint tubes. 3.3 Critical Area. The Critical Area is the area from the pin tool joint/drill pipe weld

line, towards the pipe body for a distance of 24 inches (61 cm). See Figure 3.3. 3.4 Defect. An imperfection of sufficient magnitude to warrant rejection of the

product based on the stipulations of the applicable Tuboscope procedure or the controlling specification required by the customer.

3.5 Imperfection. An imperfection is a discontinuity or irregularity in a product,

detected by methods outlined in the Tuboscope Standard Operating Procedures.

3.6 May. May is used to indicate that a provision is optional.

3.7 Scale. Visible surface particles estimated to be larger than 1/8 inch (3 mm) in any dimension which can be broken loose with a fingernail. DS-1.

3.8 Shall. Shall is used to indicate a provision is mandatory. 3.9 Should. Should is used to indicate a provision is not mandatory, but

recommended as good practice. 3.10 Slip Area. The Slip Area is the area from the box tool joint/drill pipe weld line,

towards the pipe body for a distance of 24 inches (61 cm). Additionally, anywhere on the pipe body where the slips may have been set for other operations, such as fishing. See Figure 3.3.

3.11 Standardization. The adjustment of an instrument, instrument using an

appropriate reference standard, to obtain or establish a known and reproducible response. A.S.T.M. E1316.

4.0 PERSONNEL REQUIREMENTS AND TRAINING 4.1 Personnel performing inspection techniques or NDT methods shall be qualified

and certified in accordance with Tuboscopes Written Practice. This document is contained in the Tuboscope Qualification and Certification Manual.

4.1.1 This document is based on the requirements set forth in the latest edition

of ASNT SNT-TC-1A. 4.1.2 For personnel in the Canadian Region, Magnetic Particle Testing (MT),

Ultrasonic Testing (UT), Penetrant Testing (PT) and Electromagnetic Testing (ET) certification may be supplemented by the CGSB.


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4.2 There may be one (1) or more trainees performing inspection tasks, as long as

no more than two (2) are under the training and supervision of each Tuboscope certified Level II or Level III on the job.

NOTE: For methods where a Qualification is held, it is considered equivalent to an NDT Level II.

4.3 There may be one (1) or more Level I individuals on the inspection job. The

Level I shall receive the necessary supervision and instruction from a certified Level II or III. A certified Level I individual is qualified to independently perform specific standardizations, specific tests and specific evaluations according to written operating procedures; and to record results.

4.4 For each inspection or NDT method used on the job, there shall be one (1) or

more individuals certified Level II or higher in that method. The Level II is familiar with the scope and limitations of the applicable inspection or NDT method and shall exercise assigned responsibility for the on-the-job training and guidance of trainees and Level I personnel in that method. A certified Level II individual is qualified to:

4.4.1 Independently set up and standardize applicable equipment. 4.4.2 Interpret and evaluate inspection results. 4.4.3 Assure accurate classification of a product in accordance with applicable

codes, standards and specifications. 4.4.4 Organize and report the results of the inspections performed.

4.5 In the case of mobile inspection activities, the certification data of the applicable Tuboscope personnel performing the inspections shall be available for verification at the inspection unit. For Tuboscope plant inspections, personnel certification data may be maintained at the applicable plant office.

5.0 RADIATION REQUIREMENTS Operators charged with responsibility for Electromagnetic Inspection (EMI) units, such

as the ISOLOG, Scanalog or NDT Systems Inspection Systems must be thoroughly familiar with the information contained in SOPs 307 and 309. All requirements contained in these documents which pertain to the applicable Tubsocope EMI unit must be strictly adhered to with the exception of states having requirements more stringent


SOP No. III-001





than those outlined in Tuboscope SOPs. 6.0 ACCIDENT CONTROL AND SAFETY It is the duty of each Operator charged with responsibility for any of the full body

inspection systems contained in this Tuboscope SOP manual to adhere to all applicable Company rules and regulations regarding accident control and safety. To accomplish this, each Operator must ensure safe working conditions and necessary protective equipment have been provided in all cases where appropriate for the task to be performed. Personal protective equipment typically includes, but is not limited to hard hats, goggles, and hard toe shoes.

7.0 PLANNING THE INSPECTION Quality Inspection, the key to our success, can be achieved by carefully planning each

and every phase of the inspection service. Each work day give thought to and perform the following prior to operation of the

inspection system: 7.1 Instructions and/or job assignments for members of the crew. 7.2 Ensure that all necessary equipment needed to perform the inspection is available

and in good condition. 7.3 Reasonable notice of intent to setup equipment and inspect pipe should be

given to a representative of the mill, pipe yard or other location by Tuboscope operations personnel.

8.0 INSPECTION EQUIPMENT CONDITION

All equipment used in any phase of the inspection process must be in correct operating condition, and in strict compliance with Tuboscope Engineering Design Specifications, as applicable.

9.0 EQUIPMENT REQUIREMENTS

9.1 Equipment Calibration. Equipment calibration/verification shall be in accordance with the applicable procedures or bulletins identified in 2.4.17 through 2.4.19. Calibration/verification frequency shall be in accordance with Table 9.1.

9.1.1 Light meters shall be calibrated when repaired, whenever an erratic

response is indicated and at the frequency specified in Table 9.1.


SOP No. III-001





9.1.2 The visible light sources identified in 9.2.2 through 9.2.4 shall be verified

whenever lighting fixtures change intensity and at the frequency specified in Table 9.1.

a. In addition, the Ambient Visible Light Intensity shall be checked

whenever there is a noticeable increase in visible light. b. For portable large area lighting equipment, the light intensity shall be

verified at the beginning of the job, at least once per shift thereafter and whenever the lighting fixture(s) have been re-positioned.

9.2 Visible Lighting Requirements. Visible light utilized for visual inspection shall be

furnished by either direct daylight or artificial light sources. Light sources shall meet the following requirements:

9.2.1 Direct Daylight. Direct daylight conditions do not require a check of

surface illumination. Daylight conditions are defined as the period from hour after sunrise to hour before sunset.

9.2.2 Artificial Overhead Light Sources. Artificial overhead light sources shall

have a minimum intensity of 50 foot-candles (500 lux) at the surface of the material being examined.

9.2.3 Hand Held Visible Light Sources. Hand held white lights fixtures shall

have a minimum intensity of 100 foot-candles (1000 lux) at 30 inches (76 cm) from its lens or face located beyond the bulb. The lens and reflector surfaces shall be kept clean and free from damage.

9.2.4 Ambient Visible Light Intensity. The black light inspection area shall be

darkened to such a degree that the ambient visible light intensity does not exceed 2 foot-candles (20 lux), when measured at the inspection surface.

9.3 Black Light (UV-A) Sources. Filters shall be clean and free of cracks. Other

sources of UV-A such as a flood bulb or tube are acceptable if they provide the intensity specified in 9.3.2 at the inspection distance.

9.3.1 The ultraviolet light shall have a 100 watt mercury arc lamp, minimum. 9.3.2 After a minimum of five (5) minutes warm-up, the black light source shall

produce a peak intensity of at least 1000 W/cm2 at 15 inches (38 cm)


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from its lens or face located beyond the bulb. This shall be checked at the beginning of each shift and whenever there is a noticeable decrease in black light.

NOTE: Labino lights do not require a warm-up period.

9.3.3 For special tubular-type lights in which the bulb is inserted into the pipe end, the intensity shall be measured at a distance equal to the inspection distance.

9.3.4 The intensity shall be documented.

9.4 Facility Requirements. Inspections may be performed in any of the following facilities or locations:

9.4.1 Enclosed Facility. Inspections performed in an enclosed facility are not

subject to the restrictions of inclement weather or daylight conditions. 9.4.2 Mobile Location. Inspections performed in outside pipe yard facilities or

well site locations are subject to the restrictions of inclement weather i.e.; rain, high wind, snow, ice on pipe surface(s), hail, etc. Inspections are prohibited from being performed under these conditions, however, snow, ice and hail may be removed from pipe surfaces to permit inspections to take place.

9.4.3 Inspections shall conclude hour before sunset and shall not

commence until hour after sunrise unless an adequate light source is provided which meets the requirements of 9.2.2.

9.5 In addition to this SOP manual, the latest edition of the following reference

documents, applicable to the inspection(s) or test(s) performed, shall be available at the job location.

9.5.1 Applicable customer specification(s). 9.5.2 A.P.I. Specification 5D - Drill Pipe. 9.5.3 A.P.I. Specification 5T1 Imperfection Terminology.

9.5.4 A.P.I. Specification 7 Specification for Rotary Drill Pipe Stem Design

and Operating Limits.


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9.5.5 A.P.I. Recommended Practice 7G Recommended Practice for Drill

Stem Design and Operating Limits.

9.5.6 Standard DS-1 Drill Stem Design and Inspection.

9.5.7 NS-2 North Sea Drillstring Inspection Standard. 9.5.8 Other applicable specification/code related to any non-API product. 9.6 Tuboscope EMI Buggy Reference Standards

9.6.1 Eight (8) Hole Flux Leakage Standard. Only Tuboscope manufactured eight (8) hole reference standards shall be used to standardize the inspection system. These reference standards are available from the warehouse using the following part numbers.

Pipe Size Part # 2-3/8 3509000010 2-7/8 3509010010 3-1/2 3509020010

4 3509030010 4-1/2 3509040010

5 3509050010 5-1/2 3509060010 5-7/8 350180010 6-5/8 3509080010

a. The eight (8) holes are partial radially drilled, in the standards

outside surface, to provide a similar electronic response. b. The holes shall have an approximate axial spacing of 2-1/2 inches

(6,4 cm) such that each will produce its own distinct signal on the chart.

c. The holes are spaced circumferentially at 45 intervals around the

pipe such that each hole passes under one (1) detector. d. The holes shall have an approximate diameter of 0.035 inches (0,89

mm) (#65 drill bit).


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e. Each standard contains a longitudinal groove used to guide the

buggy along the standard and prevent skew during standardization. An arrow denotes the appropriate direction of buggy travel.

9.6.2 Wall Thickness Standard. Only Tuboscope manufactured wall reference

standards shall be used to standardize the inspection system. These reference standards are available from the warehouse using the following part numbers.

Pipe Size Part #

2-3/8 NDT0031403 2-7/8 NDT0031404 3-1/2 NDT0031405

4 NDT0031406 4-1/2 NDT0031407

5 NDT0031408 5-1/2 NDT0031409 5-7/8 3901800010 6-5/8 NDT0032174

a. Each standard contains an approximate 6 inch (15 cm) long external

wall reduction which at its maximum point is about 5% in depth. 9.7 Endsonic Reference Standards

9.7.1 The reference standard shall be made from ultrasonically defect free material with the same diameter, wall thickness, comparable surface finish and acoustic properties as the material being inspected. Standards may be prepared in the field if they comply with requirements in this SOP or may be purchased through warehouse.

9.7.2 Tuboscope manufactured Endsonic reference standards are available

from the warehouse using the following part numbers. These standards also contained a machined internal wall reduction (see 9.7.7).


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Pipe Size Wall (in.) Part # 2-3/8 0.280 367438-0010 2-7/8 0.362 374765-0010 3-1/2 0.368 363489-0010 3-1/2 0.449 363756-0010

4 0.330 363721-0010 4-1/2 0.337 363490-0010 4-1/2 0.430 367096-0010

5 0.362 363491-0010 5 0.500 363759-0010

5-1/2 0.361 363492-0010 5-1/2 0.415 363757-0010 5-7/8 0.415 390533-0010 6-5/8 0.330 367097-0010 6-5/8 0.362 374766-0010

9.7.3 Notches manufactured in the field shall be manufactured by the EDM

process and controlled in accordance with the applicable requirements of SOP III-600.

9.7.4 Notches. As a minimum, one (1) transverse notch shall be placed on the

internal surface and one (1) on the external surface of the reference standard to be used for shear wave standardization.

Tuboscope has determined through experimentation, with notches of varying lengths and varying depths, that the following notch dimensions were best suited to find the type of defects most commonly found in used drill pipe, mainly minute fatigue cracks:

a. Notch length shall not exceed 3/16 inches (4,76 mm) at full depth. b. Notch depth shall be 7.5% of the specified wall thickness, + 0.004

inches (0,10 mm). c. Notch width shall not exceed 0.040 inches (1,02 mm). d. Notch orientation shall be 90, 2 from the longitudinal axis.


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Note: A 10% ID transverse notch was added on all prior standards to be used only when extreme noisy conditions will preclude the use of the 7.5% notch or when specifically requested by customer. 9.7.5 To comply with DS-1, two (2) extra notches may be added to the above

standard or a new standard may be manufactured with notches complying with the following dimensions.

a. Notch length shall not exceed 1/2 inches (12,7 mm) at full depth.

b. Notch depth shall be 5% of the specified wall thickness, + 0.004

inches (0,10 mm).

c. Notch width shall not exceed 0.040 inches (1,02 mm). d. Notch orientation shall be 90, 2 from the longitudinal axis.

9.7.6 When the inspection is performed in accordance with this SOP, the

notch specifications given in 9.7.4 shall govern. If the inspection is performed in accordance with DS-1, the notch specifications given in 9.7.5 shall prevail.

Note: When ordering older standards from warehouse you will need to specify

to add the 5% notches to comply with DS-1 or customer specifications.

9.7.7 Wall Reduction. To facilitate compression wave standardization, an internal wall reduction with a remaining body wall of 80%, 0.005 inches (0,13 mm) shall be machined or ground on the standards internal surface.

10.0 MATERIAL CONDITION 10.1 Prior to performing any inspection, the applicable areas of all material shall be

free from any rust, oil, scale, coating drip lines or coating which is not adhered to the material surface which may be detrimental to the examination. In addition to 14.0 of this procedure, specific surface preparation requirements shall be outlined in the applicable procedure(s) contained in this manual.

10.1.1 Scale. Determine if there is "any" visible scale on the pipe, according to

an experienced and qualified inspector (we must be absolutely sure it is actually scale, not be confused with surface oxidation or discoloration with scale). If this is the case, the appropriate management (sales and/or operations) should contact the customer immediately to notify


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them of the condition of the pipe and recommend the removal of the scale prior to beginning the inspection process. Refer to 3.7 for the DS-1 definition for scale. If the customer is notified and they make the decision not to have the material cleaned prior to inspection, it shall be so noted on the report.

10.1.2 Excessive Pitting. If there is any "actual" visible pitting (not to be

confused with surface roughness) on the internal or external surface of the drill pipe, according to an experienced and qualified inspector, the appropriate management (sales and/or operations) should contact the customer immediately to notify them of the condition of the pipe. The customer should be asked to either accept or reject the string based on their definition of excessive pitting, or cosmetic appearance. Their reply to accept or not accept the string shall be documented on the inspection report and also on the run sheet in the remarks column of each individual joint having visible OD pitting.

10.2 Any material having questionable straightness shall be further examined as to

whether the straightness condition will have a detrimental effect on the inspection activity or the applicable inspection equipment. Evaluation of material for straightness shall be performed in accordance with SOP III-002.

10.3 All material with threaded or beveled ends shall be visually checked after

completion of the inspection order to insure the proper installation of thread protectors.

11.0 IDENTIFICATION OF MATERIAL

11.1 At the beginning of each inspection order, each piece to be inspected shall be identified with a permanent identification number, unless otherwise directed by the customer. Serial numbers assigned by the rental company or drilling contractor are acceptable provided they are unique and allow for traceability.

11.2 Markings shall be permanent in nature and shall NOT be placed in areas which

are prone to fatigue stresses or where sealing occurs. No markings shall be allowed on rotary shoulders, stress relief grooves or on elevator slip recess grooves.

11.3 Markings are typically die stamped on the 35 sloping shoulder of the pin tool

joint. Other low stressed sections of the tool joint where the markings will carry through operations may be used (i.e. milled slots) as described in Table 11.3. Cold steel stenciling shall not be made on the outer surface of the tube body,


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unless specifically ordered by the Customer. 11.4 Steel stamp identification should include the Length No., Tuboscope Script T,

punch marks for the final clarification, month and year of the inspection. Below is an example.

50 T: 4 8

The above example indicates the pipe is joint number is 50, it was inspected by Tuboscope, it is classified as Class 2, inspected in April and the year was 1998.

For US operations, only a serialized the Script T, issued by Quality/Technical Services (QTS), shall be used.

NOTE: At times, pipe will be inspected from rental firms and a permanent number will already be steel stenciled on the pipe. All that would be required is to steel stencil the script T, the punch mark classification and the date inspected, plus record the permanent stenciled number for each length of pipe.

12.0 CUSTOMER NOTIFICATIONS The responsible Tuboscope Inspector shall notify their immediate supervisor if any of

the following occur. Tuboscope supervisory personnel shall notify the customer as required.

12.1 The rejection rate on an order exceeds 10% after inspection of 50 lengths or

pieces. 12.1.1 If more than 50% of the lengths of pipe are rejected, the QTS

Department should be informed as soon as possible by the Field Superintendent or Division/District Manager.

12.2 There is a delay in inspection of longer than two (2) hours. 12.3 The job is shut down prematurely. 12.4 Any deviation from the required procedure is necessary. 12.5 Grinding to remove defects is necessary and prior permission from the customer

has not been granted. Removal of defects by Tuboscope may require additional charges.


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NOTE: Fatigue cracks are prohibited from being removed and are cause for rejection in all cases.

12.6 There will be insufficient material to meet the order requirements, based on the

number of joints available and the reject rate. 12.7 Stencils/markings are not legible or do not match the work order. 12.8 Thread protectors are missing, damaged or are not composite type. 13.0 REMOVAL OF THREAD PROTECTORS 13.1 When required by the inspection/test process, the thread protectors shall be

removed and stacked or placed in such a manner as to prevent contamination. Any damaged or defective thread protectors should be segregated.

13.2 If protectors become contaminated or if the type of thread compound will be

changed, the protectors shall be cleaned with an approved solvent. The protectors shall be stacked such that cleaning fluid will drain from the protectors and prevent contamination of thread lubricant during re-installation. Protectors which become contaminated after cleaning shall be re-cleaned prior to installation.

13.3 Care shall be used when removing thread protectors to prevent damage to pipe

and sealing surfaces with pipe wrenches. 14.0 INSPECTION SURFACE PREPARATION 14.1 For tool joint inspection, clean the internal and external threads and seals. This

area is detailed in Figure 14.1 as area A. 14.2 For inspection of the tube body, insure that any drill pipe rubbers have been

removed. Remove any loose scale, sticky coatings, grease, oil, or dirt from the entire length of the tube from upset to upset. Clean the internal surfaces as required to remove dried drilling mud or cement residue which may affect the inspection adversely.

14.3 Except for liquid penetrant testing, an absorbent substance may be applied to

the cleaned area to speed drying. 14.4 Cleaning materials and other foreign debris incompatible with the inspection


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process shall be removed from the connections and pipe ends with compressed air. Prior to dry magnetic particle inspection or liquid penetrant inspection, surfaces to be inspected shall be completely dry.

14.5 Uncoated threads that have been cleaned shall not be left overnight without

protection from moisture, unless the material is under a covered facility. Thread compound, soluble inhibitor or a tarp/plastic covering shall be applied.

NOTE: If tarps/plastic covering are used and cleaned areas are re-contaminated, re-cleaning shall be required.

14.6 Solvents and hazardous residue resulting from cleaning shall not be hazardous

to the material being inspected nor contact the earth and shall be collected and disposed of in accordance with the inspection location regulations for handling of hazardous waste.

15.0 RE-INSTALLATION OF THREAD PROTECTORS

15.1 After all inspection processes are completed which originally required thread protectors removed, ensure that the threads are clean and dry. Lubricate the threads with the thread compound. Lubricate the full threaded area, including seals and thread roots, for the entire thread circumference.

15.1.1 A thread compound which meets API RP 7A1 (50% Zinc based) shall be

used, unless specified otherwise by the customer.

15.2 In cold climates, it may be necessary to warm the thread compound in order to apply it. Thread compounds shall not be thinned for any reason.

15.3 Thread compounds shall be stirred prior to use to ensure uniform mixing of

components. 15.4 The thread compound container shall be covered when not in use.

Contaminated thread compound shall not be used. 15.5 Visually inspect each thread protector prior to installation for damage. Thread

protectors shall be installed wrench tight.

15.5.1 Damaged thread protectors shall be rejected. 15.5.2 Care shall be used when installing thread protectors to prevent damage

to pipe surfaces with pipe wrenches. Strap type wrenches shall be used


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in cases where damage is probable. 16.0 EVALUATION OF IMPERFECTIONS 16.1 All imperfection indications resulting from visual, ultrasonic, EMI, magnetic

particle and liquid penetrant inspections shall be evaluated. For automated scanning equipment, imperfection indications (signals), as defined in the applicable Tuboscope SOP shall be evaluated.

16.2 Except for thread and seal surfaces, imperfections shall be evaluated in

accordance with the requirements of SOP III-002, unless specified other-wise by the customer.

16.3 Unless specified otherwise by the customer, imperfections on threads and

associated seal surfaces shall be evaluated in accordance with SOP III-100. 17.0 ACCEPTANCE CRITERIA

17.1 If a defect or an imperfection indication(s) is not present on the piece inspected,

the piece shall be classified as acceptable by the specific inspection(s) employed. Imperfections or dimension variations are classified as defects if they meet the criteria given in the applicable Tuboscope SOP identified in 2.4.12 and 2.4.13.

17.2 Except for thread and seal surfaces, imperfections shall be evaluated in

accordance with the requirements of the applicable Table 7.2.3 - 1 through 7.2.3 18 in SOP III-002, unless specified otherwise by the customer.

17.3 Unless specified otherwise by the customer, imperfections on threads,

associated seal surfaces and connection dimensions shall be evaluated in accordance with SOP III-100.

18.0 POST INSPECTION PROCEDURES 18.1 Drill Pipe Inspection Classification. Each length of drill pipe inspected shall be

classified into one (1) of the following categories: 18.1.1 Acceptable material, according to the results of the specific inspection(s)

or test(s) performed which meets the criteria for Premium Class in accordance with the applicable Table 7.2.3 - 1 through 7.2.3 18 in SOP


SOP No. III-001





III-002, shall be identified by two (2) white bands in addition to the one (1) center punch mark between the month and year steel stamp markings.

18.1.2 Acceptable material, according to the results of the specific inspection(s)

or test(s) performed which meets the criteria for Class 2 in accordance with the applicable 7.2.3 - 1 through 7.2.3 18 in SOP III-002, shall be identified by one (1) yellow band in addition to the two (2) center punch marks between the month and year steel stamp markings.

18.1.3 Acceptable material, according to the results of the specific inspection(s)

or test(s) performed which meets the criteria for Class 3 in accordance with the applicable Table 7.2.3 - 1 through 7.2.3 18 in SOP III-002, shall be identified by one (1) orange band in addition to the three (3) center punch marks between the month and year steel stamp markings.

18.1.4 Material containing cracks, washouts (holes) or an API defect(s) not

removable by grinding or filing and identified by red paint markings. 18.1.5 Material containing a customer specified defect(s) not removable by

grinding or filing and identified by customer specified paint markings. 18.2 Inspection Classification Markings. Inspection markings shall not be placed over

manufacturer markings, unless an imperfection exists under such a marking. In the absence of customer specifications, the following shall be used:

18.2.1 The color of the classification band shall be in accordance with 18.1 and

placed on the pipe and tool joint as shown in Figure 18.2.1. Paint or ink of long-lasting quality shall be used and shall not be applied on threaded areas.

18.2.2 Classification bands should be at least 2 inches (5,1 cm) wide and

placed approximately 2 feet (0,6 m) from the pin tool joint. 18.2.3 Tool Joints. Tool joints shall be classified separately from the drill pipe.

Tool joints which do not contain any defects do not require a classification band. Tool joints which are defective shall receive classification bands in accordance with Table 18.2.3, next to the bevel.

a. Tool joints which contain cracked threads may be classified for shop

repair if the re-cut tool joint would still have sufficient tong space.


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1. To estimate this, measure the length of the threads on the

connection to be re-cut. 2. Next, measure from the crack location towards the pipe body the

distance measured in 18.2.3.a.1. If the portion of the tool joint remaining is greater than the minimum tong space required, the tool joint may be marked for shop repair.

3. Thread and shoulder damage (corrosion and mechanical

damage) are typical of connections which can be shop repaired. 18.2.4 Markings, other than classification bands and permanent die stamp

markings shall be printed or stenciled and shall be legible. White or silver paint or ink shall be used; except that yellow or black may be used on white, machined or chrome like product surfaces.

a. For drill pipe body defects, a stencil or printed description (or code)

shall be stenciled or written adjacent to the defective area indicating the reason for rejection.

b. For rotary shouldered connections, in addition to the classification

band, a stencil or printed description (or code) shall be stenciled or written on the tool joint or adjacent to a BHA connection, indicating the reason for the classification.

18.3 Bottom Hole Assembly (BHA) Inspection Classification. Each BHA component

inspected and determined to be acceptable shall be stenciled with OK TUBO next to each connection.

18.3.1 Defective BHA connections shall receive classification bands and

markings in accordance with 18.2.3 and 18.2.4. 18.4 All grinds or file marks on acceptable material shall be contoured to remove

abrupt changes in wall thickness. Grinds shall be verified by ultrasonic thickness measurements to ensure sufficient remaining wall thickness. The outside diameter of the tube in the area of the grind shall be checked to ensure the change in diameter has not changed the classification of the tube. For automated inspections, the minimum thickness and location of each grind shall be recorded on the appropriate inspection prove-up report or Drill Pipe Inspection Report sheet. All external grinds shall be coated with rust inhibitor or


SOP No. III-001





black enamel paint, unless specified otherwise by the customer. 18.5 Pipe Segregation. Acceptable pipe shall be segregated from all other pipe when

practical. 18.6 Inspection Records 18.6.1 One (1) or more Drill Pipe Inspection Report sheets shall be completed

to list by piece number the inspection results accurately and with enough detail to assure that the condition and disposition of any inspected piece can be determined. In addition, a Drill Pipe Summary Report shall be completed for each inspection service order.

18.6.2 Inspection records shall be completed at the end of the job before

leaving the location. The report shall contain the name, signature and employee certification number of the Tuboscope Inspector responsible for the information on the report.

18.6.3 Where applicable, defect terminology on inspection records shall comply

with API Standard 5T1, unless specified otherwise by the customer. 18.6.4 All inspection records shall be retained in accordance with QSP-42-02. 18.6.5 The information marked on each rejected piece shall be the same as

that recorded on the Drill Pipe Inspection Tally sheet. All pieces shall be verified to have been color coded and stenciled properly.

18.6.6 The following shall be noted on the inspection report: a. The total number of accepted lengths and corresponding footage, if

required by the customer. The classification band color shall be identified.

b. The total number of rejected lengths and corresponding footage, if

required by the customer. The classification band color shall be identified.

c. The total number of lengths inspected and total footage, if required

by the customer. d. The total number of customer rejected lengths and corresponding

footage. The classification band color shall be identified.


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e. Pertinent customer information such as well charges, purchase order

number, supplier release numbers, etc.

Weld Zone

Weld Line

Tool Joint

24 in. (61 cm)

Critical Area

Internal Upset

Weld Neck

Weld Line

24 in. (61 cm)

Slip Area

Internal Upset

Tool JointWeld Zone

Weld Neck

Figure 3.3 Slip / Critical Areas


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Table 9.1 - Equipment Verification / Calibration Frequency

Equipment Description Minimum

Frequency(months)

Equipment Description Minimum

Frequency(months)

Artificial Overhead Light Sources 4 Micrometer Standard (End Measuring Rod) 12

Hand Held Visible Light Sources 4 Lead Gauge 4 Ambient Visible Light Intensity 4 Lead Gauge Setting Standard 24 Surface Thermometer 12 Dial Caliper 4 Contact Pyrometer 12 Micrometer Depth Gauge 4 Dial Depth Gauge 4 Micrometer 4 Dial Indicator 4 Ultrasonic Flaw Detector 6 Light Meter 4 Ultrasonic Waveform Monitor 6 Magnetizing Source Ammeter 4 Portable Ultrasonic Thickness Gauge 6 Mechanical Magnetometers 4 Electronic Gaussmeter 6 AC Yoke 4 API Spec 7 Master Ring and Plug Gauges 84

Rotational / Linear Speed Indicator Meter 6

API Spec 7 Working Ring and Plug Gauges 4*

Inductive Ammeter 4 Radiation Survey Meter 6 Magnetic Pulser 4 Encoder Wheel (for pipe length) 1 * Working gauges may be verified after 500 documented usages, however, they shall at least be verified annually.


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Table 11.3 - Permanent Marking Locations

Equipment Marking Location

Drill Pipe and Heavy Weight Drill Pipe On the taper of the pin tool joint or in the milled slot on the pin tool joint. Spiral Drill Collars On flat of spiral, as close as possible to the pin. Subs < 2 feet (0,6 m) in length In milled slot, 3/16 inch (0,2 mm) deep, near mid-length. Slick Collars and Subs > 2 feet (0,6 m) in length

In milled slot, 3/16 inch (0,2 mm) deep, 2 to 3 feet (0,6 to 0,9 m) from pin.

Kellys On the taper of the box connection.

Valves In milled slot, or on the outside surface outside of the tong space. The milled slot must not alter the strength of the valve body

AA

Figure 14.1


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CLASSIFICATION PAINT BANDSFOR DRILL PIPE

TOOL JOINTCONDITION BANDS

STENCILS FOR PERMANENTMARKING FOR CLASSIFICATION

OF DRILL PIPE BODY

Figure 18.2.1

Table 18.2.3 - Tool Joint and BHA Classification Markings

Condition RP 7G & NS-2 DS-1 So. Louisiana

Shop Repairable Red Blue Yellow

Field Repairable (refacing required) Green Green White on the shoulder

Scrap (reject) Red Red Red

Undersize Red Red Green