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Drilling Services

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Tuboscope is a global leader in inspection, corrosion control, hardbanding and much more. Our integrated services approach maximizes the life cycle of your tubulars while ensuring safe, successful and profitable drilling programs in the most challenging drilling environments.

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Articles & Technical Papers

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Multimedia

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Tubular Coating Process

TCS Hardbanding

75 Years of Quality, Innovation and Service

TK Liner

Tubular Inspection System

WellChek Onsite Tubing Inspection

Tubular Wall Mapping with Laser OD Measuring

Tuboscope: Meeting Today's Challenges

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Production Services

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Coming Soon
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Mill-NDT Systems

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Recognized as the industry leader in tubular inspection, Tuboscope offers an array of equipment and services for all stages of pipe manufacturing, from the steel mill to its eventual use.

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EMI Equipment

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EMI Equipment

EMI Equipment Utilizing the latest technologies, our fully automated non-destructive EMI units provide accurate flaw detection, evaluation, and classification of ferrous steel pipe and tubes in accordance with API, ASTM and other international industry standards.

For more information click on the link below Amalog™ Sonoscope™ EDM Notch Cutter Server-Based Digital Instrumentation
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Combination EMI & UT

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Sonoscope™ Transverse & Tri-dimensional Flaw Detection

The Sonoscope™ EMI unit is equipped with an air-actuated, multi-detector system, installed within a stationary coil assembly. These coils induce a high-strength longitudinal magnetic field into the wall thickness of the pipe, while the detector shoes, incorporating proprietary sensor coils, detect transverse and tri-dimensional surface-breaking flaws on both the inside and outside pipes surfaces.

For more information click on the link below Sonoscope™
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Combination EMI & UT

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Amalog™ Longitudinal Flaw Detection

The Amalog inspection unit is equipped with a dual-shoe detection system, integrated into a rotating coil magnetizer assembly. The coils induce a high-strength circumferential magnetic field into the wall thickness of the pipe, while the detector shoes, incorporating proprietary sensor coils, detect longitudinal surface-breaking flaws on both the inside and outside pipe surfaces.

For more information click on the link below Amalog™
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Combination EMI & UT

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Electric Discharge Machine (EDM) Notch Cutter

Tuboscope’s EDM Notch Cutter cuts precise internal and external transverse, longitudinal, or oblique notches into the ID and OD surfaces of the pipe for accurate calibration of inspection equipment prior to EMI and/or UT inspections.

Our EDM wall reduction tool provides machined reductions for UT test applications.

All test notches are made in accordance with API, ASTM and other international industry standards.

For more information click on the link below EDM Notch Cutter™
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Combination EMI & UT

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Server-Based Digital Instrumentation

Our Server-Based Digital Instrumentation system is designed to be used with any stand-alone or combined configuration from Tuboscope’s line of inspection units.

This computerized instrumentation package provides total control of all:
For more information click on the link below Server-Based Digital Instrumentation
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UT Equipment

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UT Equipment

UT Equipment

Our proprietary high-speed full-body UT systems detect, evaluate and classify internal and external surface-breaking flaws on ferrous and non-ferrous steel pipes.

For more information click on the link below Truscope™ Full Body UT Truscan Ultrasonic EDM Notch Cutter™ Server-Based Digital Instrumentation
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Combination EMI & UT

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Truscope™ Full Body UT Inspection

Tuboscope’s Truscope™ is a full body rotary ultrasonic (UT) inspection system, designed to inspect tubulars from 2-3/8 inches (60 mm) to 16 inches (406 mm) in diameter, and with a linear conveyor speed of up to 200 FPM (1 m/s).

Inspection capabilities include:

For more information click on the link below

Truscope™ Full Body UT Inspection
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Combination EMI & UT

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Truscan™ Ultrasonic Flaw Detection and Wall Thickness Measurement

Tuboscope’s TruScan(TM) inspection system utilizes ultrasonic (UT) techniques for the inspection of pipe during the manufacturing process, in a finishing facility or after it is used in service.

Size Capabilities - 2-3/8 inches (60 mm) to 24 inches (610 mm) in diameter.

Inspection capabilities include:

For more information click on the link below

Truscan™ Ultrasonic Flaw Detection
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Combination EMI & UT

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Combination EMI & UT

Combination EMI UT

Tuboscope’s Truscope A/S (Truscope -Amalog-Sonoscope) Inspection System combines our proprietary EMI and UT inspection units into one package for a full-body inspection across a large range of pipe diameters.

For more information click on the link below Truscope A/S™ EDM Notch Cutter Server-Based Digital Instrumentation
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Combination EMI & UT

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Truscope A/S™

Tuboscope’s Truscope A/S (Truscope -Amalog-Sonoscope) Inspection System combines our proprietary EMI and UT inspection units into one package for a full-body inspection across a large range of pipe diameters.

In a single pass, this high-speed unit detects flaws, evaluates and classifies pipe in accordance with API 5CT, 5L, 5DP, as well as numerous other international specifications for non-destructive inspection of tubular products.

Inspection capabilities:
Pipes can be seamless or ERW, manufactured of ferrous or non-ferrous alloy materials, and with a variety of end conditions:
For more information click on the link below Truscope A/S™
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Inspection

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Why inspect drill pipe?

Drill pipe is the work horse of down hole tubular strings - it rotates the drill bit, provides a conduit to carry drilling mud to lubricate the drill bit and pushes mud and bottomhole shavings up the outer surface to the top of the hole.

To prevent downhole failures, it is crucial to identify manufacturing and drilling related defects.

Tuboscope provides the necessary inspections to identify serviceable pipe for all drilling operations including deviated and horizontal wellbores.

  • Ultrasonic Testing (UT)
  • Electromagnetic Inspection (EMI)
  • Multiple Dimensional Tool Joint Checks (Box and Pin)

Tuboscope inspection services are carried out in accordance with industry standards such as API, DS-1, and NS-2.

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Coatings

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Drilling environments are aggressive and are tough on drill pipe. To manage your assets and maximize the lifecyle of your drill pipe, proper care and handling programs are essential.

Tuboscope's internal plastic drill pipe coatings protect your entire drill string and deliver superior returns on your investment.

Benefits:

Corrosion Control

Corrosion can exacerbate the stresses that severe drilling operations inflict upon your drill pipe, leading to the development of fatigue cracks, and ultimately catastrophic downhole failures such as washouts or twist offs.

Hydraulic Improvements

Reduced surface roughness of the internal coating versus bare steel can minimize pump pressures required to provide sufficient fluid flow and can allow for a greater volume of fluid to be circulated at the same pressures.

Prevention of Scale Deposits

Reduced surface roughness mitigates the deposit of scales, which minimizes the need for costly chemical treatments.

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Machining

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A string of drill pipe can be the most expensive asset on the drilling rig, so it should have the longest serviceable life possible. Tuboscope's Machining services help extend the life of your drill pipe by restoring your drill stem components to their optimal condition.

Thread Repair

On API rotary shouldered connections, Proprietary connections & Premium two-step connections.

Tool Joint Rebuilding

The cost of rebuilding is approximately 30-55% the cost of new drill pipe. Our unique process restores worn tool joints on drill pipe, drill collars, and heavy weight drill pipe to original specifications for extended service.

Manufacture of subs and manifold fittings

Tuboscope manufactures all drill string substitutes from new materials. A full line of sub stock material with mill certification is inventoried at all machine shops.

What sets Tuboscope apart from standard machine shops?

  • Industry leading technologies
  • The latest CNC machinery
  • API trained technicians
  • Certified inspection and gauging practices
  • Stringent quality and safety programs
  • Worldwide footprint - when and where you need us

Many of our facilities are API certified and are licensed to cut proprietary connections, including Grant Prideco.

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Hardbanding

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Harsh drilling conditions such as extended reach drilling put eccentric wear on tooljoints, so protecting your investment in drill pipe and casing is important.

To increase productivity, lower costs and gain greater reliability from your drill string Tuboscope offers the latest hardbanding alloys with the best combination of tool joint wear and casing protection. Tuboscope's TCS Hardbanding alloys help ensure tool joint integrity, crack resistance, and a lack of spalling in overlay material.

Tuboscope is the only oilfield hardbanding service company that offers a single source for wire manufacture, wire sales, new pipe application and reapplication worldwide.

With mobile and fixed units strategically located around the world, TCS™ Hardbanding is available in all major oilfield markets.

Benefits of TCS Casing friendly Hardbanding (TCS 8000 and TCS Titanium)

  • Superior casing wear protection
  • Crack free
  • Extremely low coefficient of friction
  • Extended tool joint life
  • High stress abrasion resistance
  • No shielding gas required
  • Unlimited reapplication in the field
  • Superior adhesion means non-spalling
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Asset Management

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Tuboscope's sophisticated asset record management systems provide on the spot alerts for inspection frequency, hardband reapplication and coating performance.

  • Detailed reports
  • In-depth analysis upon completion of job
  • Innovative technologies used in data acquisition
  • Complete premium pipe analysis
  • Tool joint wear data
  • Hardband and coating performance
  • Recommended repairs
  • Historical inspection analysis
  • Inventory management
  • Purchase optimiization

Our TruData Inspection report can reduce risk by identifying operational problems, improper care and handling as well as ensuring your pipe is fit-for-purpose for specific drilling applications.

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Specialty Inspection Services

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Tuboscope SIS is the leader in global inspection, repair and maintenance. With our skilled personnel, equipment and experience we ensure your rigs meet global compliance and inspection requirements.

  • Rope Access
  • Derrick Services
  • DROPS
  • Load Testing
  • Lifting Gear Inspection
  • NDT Inspection

In the yard, on location or in transit, you get the quality inspection, safety and maintenance services you need, when and where you need them.

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DS-1 Inspections Guidelines

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DS-1 ™ Category 1

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DS-1™ Category 1

Tool Joint - Visual Connection

The tool joint connection is examined to determine grade, condition of seal, threads, hardfacing, bevel, box swell and pin stretch

Tube Body - Visual

The inside and outside surfaces are examined to determine general conditions.

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DS-1 ™ Category 2

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DS-1 ™ Category 2

Tool Joint - Visual Connection

The tool joint connection is examined to determine grade, condition of seal, threads, hardfacing, bevel, box swell and pin stretch

Tube Body - Dimensional 1

The dimensional measurement of the tool joint O.D., I.D., box shoulder width, tong space, box swell.

Tube Body - Visual

The inside and outside surfaces are examined to determine general conditions.

Tube Body - O.D. Gauge

The tube body outside diameter is mechanically gauged from upset to upset to determine abrasive wear or mechanical damage.

Tube Body - Ultrasonic Wall Thickness

Minimum remaining body-wall is determined at point of maximum wear by utilizing ultrasonic wall measurements.

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DS-1 ™ Category 3

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DS-1 ™ Category 3

Tool Joint - Visual Connection

The tool joint connection is examined to determine grade, condition of seal, threads, hardfacing, bevel, box swell and pin stretch

Tool Joint - Dimensional 1

The dimensional measurement of the tool joint O.D., I.D., box shoulder width, tong space, box swell.

Tube Body - Visual

The inside and outside surfaces are examined to determine general conditions.

Tube Body - O.D. Gauge

The tube body outside diameter is mechanically gauged from upset to upset to determine abrasive wear or mechanical damage.

Tube Body - Ultrasonic Wall Thickness

Minimum remaining body-wall is determined at point of maximum wear by utilizing ultrasonic wall measurements.

Tube Body - Electromagnetic 1

An electromagnetic inspection performed on the tube body utilizes an active longitudinal D.C. magnetic field and a detector unit which travels the length of the pipe body. Magnetic flux disturbances caused by transverse or three-dimensional defects such as fatigue cracks or corrosion pits are detected and recorded.

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DS-1 ™ Category 4

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DS-1 ™ Category 4

Tool Joint - Visual Connection

The tool joint connection is examined to determine grade, condition of seal, threads, hardfacing, bevel, box swell and pin stretch

Tool Joint - Dimensional 2

Additional to Dimensional 1 box counterbore depth, box counterbore diameter, bevel diameter, box seal width and pin neck length.

Tube Body - Visual

The inside and outside surfaces are examined to determine general conditions.

Tube Body - O.D. Gauge

The tube body outside diameter is mechanically gauged from upset to upset to determine abrasive wear or mechanical damage.

Tube Body - Ultrasonic Wall Thickness

Minimum remaining body-wall is determined at point of maximum wear by utilizing ultrasonic wall measurements.

Tube Body - Electromagnetic 1

An electromagnetic inspection performed on the tube body utilizes an active longitudinal D.C. magnetic field and a detector unit which travels the length of the pipe body. Magnetic flux disturbances caused by transverse or three-dimensional defects such as fatigue cracks or corrosion pits are detected and recorded.

Tube Body - MPI Slip/Upset

Dry magnetic particles are applied to the outside surface of the slip and upset area to detect transverse and three-dimensional flaws. From pin shoulder out to 36" / box shoulder out to 48".

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DS-1 ™ Category 5

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DS-1 ™ Category 5

Tool Joint - Visual Connection

The tool joint connection is examined to determine grade, condition of seal, threads, hardfacing, bevel, box swell and pin stretch

Tool Joint - Dimensional 2

Additional to Dimensional 1 box counterbore depth, box counterbore diameter, bevel diameter, box seal width and pin neck length.

Tool Joint - Backlight Connection

Wet fluorescent magnetic particles are applied to the connection surface under hood and the outside surface of the box looking for heat checking.

Tube Body - Visual

The inside and outside surfaces are examined to determine general conditions.

Tube Body - O.D. Gauge

The tube body outside diameter is mechanically gauged from upset to upset to determine abrasive wear or mechanical damage.

Tube Body - Electromagnetic 2

An electromagnetic inspection system utilizing an active longitudinal D.C. magnetic field and a gamma wall gauge (note; FLUT1 or EMI1 with UT wall reading may be substituted).

Tube Body - MPI Slip/Upset

Dry magnetic particles are applied to the outside surface of the slip and upset area to detect transverse and three-dimensional flaws. From pin shoulder out to 36" / box shoulder out to 48".

Tube Body - UT Slip/Upset Area

An ultrasonic shear-wave technique is used to inspect the critical, high-stress upset run-out and adjacent tube body end areas for transverse fatigue cracks.

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DS-1 ™ HDLS

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Tool Joint - Visual Connection

The tool joint connection is examined to determine grade, condition of seal, threads, hardfacing, bevel, box swell and pin stretch

Tool Joint - Dimensional 2

Additional to Dimensional 1 box counterbore depth, box counterbore diameter, bevel diameter, box seal width and pin neck length.

Tool Joint - Traceability

To verify an individual number is traced to its mill certificate and material test reports.

Tool Joint - Backlight Connection

Wet fluorescent magnetic particles are applied to the connection surface under hood and the outside surface of the box looking for heat checking.

Tube Body - Visual

The inside and outside surfaces are examined to determine general conditions.

Tube Body - O.D. Gauge

The tube body outside diameter is mechanically gauged from upset to upset to determine abrasive wear or mechanical damage.

Tube Body - Ultrasonic Wall Thickness

Minimum remaining body-wall is determined at point of maximum wear by utilizing ultrasonic wall measurements.

Tube Body - FLUT 2

An ultrasonic inspection performed on the tube body utilizes the shear wave and compression wave techniques to inspect in longitudinal, transverse and oblique directions to include wall thickness measurements.

Tube Body - MPI Slip/Upset

Dry magnetic particles are applied to the outside surface of the slip and upset area to detect transverse and three-dimensional flaws. From pin shoulder out to 36" / box shoulder out to 48".

Tube Body - UT Slip/Upset Area

An ultrasonic shear-wave technique is used to inspect the critical, high-stress upset run-out and adjacent tube body end areas for transverse fatigue cracks.

Tool Body - Traceability

To verify an individual number is traced to its mill certificate and material test reports.

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API RP 7G-2 Inspection Guidelines

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TruData Drill Pipe Report

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TruData

“Trudata™ is a comprehensive reporting management system for the classification, inspection, and repair of rotary shoulder drill stem components. The advanced reporting system provides a cradle to grave record of drill stem component inspection, connection repair, hardbanding, internal coating, has the ability to provide trend analysis of maintenance, repairs and future replacement of drill stem components.

The Trudata Inspection Report reduces risk by identifying operational problems, improper care and handling, as well as ensuring the pipe is fit-for-purpose for the specific drill application.”

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SONOSCOPE® Inspection - Standard Rack

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SONOSCOPE® Inspection - Standard Rack

The SONOSCOPE inspection evaluates service-induced defects in the used drill pipe tube body to API RP7G, DS-1 or customer specifications:

Sonoscope Inspection Process

  1. Each length is numbered sequentially on the pin-end tool joint shoulder. The month and year of inspection and the Tuboscope "T" service mark are also stenciled on the shoulder.
  2. The full length outside diameter of the tube body is gauged to determine the area of maximum O.D. wear.
  3. The pipe body is examined full length for visible cuts, mashes, gouges and other defects; close attention is given to the slip area.
  4. Ultrasonic spot measurements are taken at the area of maximum O.D. wear to establish minimum wall thickness.
  5. The SONOSCOPE electromagnetic inspection is performed on the tube body. SONOSCOPE inspection equipment utilizes an active longitudinal D.C. magnetic field and a detector unit which travels the length of the pipe body. Magnetic flux disturbances caused by transverse or three-dimensional defects such as fatigue cracks or corrosion pits are detected and recorded.
  6. A magnetic particle inspection is performed on the critical upset areas to detect O.D. fatigue cracks.
  7. The tube body is classified and identified in accordance with API RP7G or customer specifications.

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Critical Upset Area Inspection

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Ultrasonic End Area Inspection

The Tuboscope ultrasonic end area unit, utilizes the ultrasonic shear-wave technique to inspect the critical, high-stress upset run-out and adjacent tube body end areas for transverse fatigue cracks. Then the ultrasonic compression wave technique is employed to detect pitting and measure wall thickness.

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Tool Joint Inspection

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Tool Joint O.D. Measurement

Tool Joint O.D. Measurement

The outside diameter of the tool joint is measured to API RP7G or customer specifications to classify the tool joint O.D. reduction due to abrasive wear.

Tool Joint Shoulder (Face) Visual Examination

Tool Joint Shoulder (Face) Visual Examination

Tool joint shoulders are cleaned and visually examined for galls, nicks, washes, fins and other damage which would affect the pressure holding capacity and stability of the tool joint. The tool joint is also checked for bevel condition.

Tool Joint Welding Date/Grade Mark Examination

Tool Joint Welding Date/Grade Mark Examination

To determine pipe age, grade, weight per foot and possible tool joint rework, the pin base is visually examined for tool joint manufacturers' markings.

Tool Joint Shoulder (Face) Width Measurement

Tool Joint Shoulder (Face) Width Measurement

A mechanical gauge is used to measure pin and box tool joint shoulder width, including bevel, in accordance with API RP7G or customer specifications.

Tool Joint Clean and Visual Examination

Tool Joint Clean and Visual Examination

Tool joint threads and shoulders are cleaned and visually examined for thread and shoulder damage and bevel condition.

Check Tool Joint Pin Stretch - (with profile gauge)

Check Tool Joint Pin Stretch - (with profile gauge)

The tool joint pin is cleaned, and threads are visually compared to a hand-held thread profile gauge.

Check Tool Joint Pin Stretch - (with mechanical lead gauge)

Check Tool Joint Pin Stretch - (with mechanical lead gauge)

The tool joint pin is cleaned, and thread lead is measured with a dial indicator gauge to determine presence and amount of pin stretch.

Check Tool Joint Box Swelling

Check Tool Joint Box Swelling

A measurement is taken across the box inside counter-bore and compared to API Spec. 7 dimension Qc for possible indications of box swelling.

Dry Magnetic Particle Tool Joint Inspection, Type I

Dry Magnetic Particle Tool Joint Inspection, Type I

Pin and box threads, shoulders and the box O.D. surface are cleaned as required. Dry magnetic particles are applied to detect transverse cracking in pin thread roots and to detect longitudinal cracking on the box O.D. surface. Threads and shoulders are visually examined for damage.

Dry Magnetic Particle Tool Joint Inspection, Type II

Dry Magnetic Particle Tool Joint Inspection, Type II

Pin and box threads and shoulders are cleaned as required. Dry magnetic particles are applied to detect transverse cracking in pin and box thread roots. Threads and shoulders are visually examined for damage.

Wet Fluorescent Magnetic Particle Tool Joint Inspection, Type I

Wet Fluorescent Magnetic Particle Tool Joint Inspection, Type I

Pin and box threads, shoulders and the box O.D. surface are cleaned as required. Wet fluorescent magnetic particles are applied to detect transverse cracking in pin thread roots and to detect longitudinal cracking on the box O.D. surface. Threads and shoulders are visually examined for damage.

Wet Fluorescent Magnetic Particle Tool Joint Inspection, Type II

Wet Fluorescent Magnetic Particle Tool Joint Inspection, Type II

Pin and box threads and shoulders are cleaned as required. Wet fluorescent magnetic particles are applied to detect transverse cracking in pin and box thread roots. Threads and shoulders are visually examined for damage.

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Tube Body Inspection

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Sonoscope Buggy Inspection

An electromagnetic inspection performed on the tube body utilizes an active longitudinal D.C. magnetic field and a detector unit which travels the length of the pipe body. Magnetic flux disturbances caused by transverse or three-dimensional defects such as fatigue cracks or corrosion pits are detected and recorded.

Ultrasonic Full Body Inspection

An ultrasonic inspection performed on the tube body utilizes the shear wave and compression wave techniques to inspect the critical, high-stress areas for transverse fatigue cracks, corrosion, pitting, erosion and measures wall thickness. The multi-channel inspection heads travel the length of the pipe body acquiring real time data.

Tube Body Mechanical O.D. Gauging

The tube body outside diameter is mechanically gauged from upset to upset to determine abrasive wear or mechanical damage. Minimum remaining body-wall is determined at point of maximum wear by utilizing ultrasonic wall measurements.

Determine Minimum Cross Sectional Area (CSA)

Ultrasonic wall measurements are utilized to determine minimum and average pipe body-wall. Cross sectional area is computed at the point of maximum O.D. reduction with minimum remaining wall.

Dry Magnetic Particle Slip Area Inspection

Dry magnetic particles are applied to the outside surface of the slip area to detect O.D. transverse cracking.

Wet Fluorescent Magnetic Particle Slip Area Inspection

Wet fluorescent magnetic particles are applied to the outside surface of the slip area to detect transverse cracking.

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Special Services

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Heavyweight Drill Pipe Magnetic Particle Inspection - End Areas Only

Pin and box threads and shoulders are cleaned and examined for visual damage or imperfections. Magnetizing equipment is utilized to induce a longitudinal magnetic field. Magnetic particles are applied to the thread surface to detect transverse cracks.

Heavyweight Drill Pipe Magnetic Particle Inspection - Tool Joint and Center Wear Pad Taper Areas Only

Magnetizing equipment is utilized to induce a magnetic field into the upset taper and adjacent tube body. Magnetic articles are employed to detect transverse cracks on the outside surface.

Drill Collars, Kellys, Stabilizers, Subs and Core Barrels

Ultrasonic, electromagnetic, mechanical-optical and/or magnetic particle inspections are employed as required to locate defects in these items.

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Tube Body - Troubleshooting Guide

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WASHOUT

Usually occurs near pin end upset taper or in area from lower part of slip area to box end upset taper

USUAL EFFECT

  • Hole in pipe
  • Drop in mud pressure
  • String separation
  • Lost time

PROBABLE CAUSE

  • Cyclic stressing
  • Surface notching
  • Fatigue cracking

POSSIBLE CORRECTION

  • Minimize surface notching
  • Reduce stress level
  • Avoid excessive rotary speeds
  • Move bottom hole pipe up hole on trips
  • Taper transition zone
  • Use shock subs

TWIST OFF

Usually occurs near pin end and upset taper or in area from lower part of slip area to box end upset taper

USUAL EFFECT

  • String separation
  • Lost time
  • Fishing job

PROBABLE CAUSE

  • Cyclic stressing
  • Surface notching
  • Fatigue cracking

POSSIBLE CORRECTION

  • Minimize surface notching
  • Reduce stress level
  • Avoid excessive rotary speeds
  • Move bottom hole pipe up hole on trips
  • Taper transition zone
  • Use shock subs

FATIGUE CRACKING

Predominately found near pin end upset taper and in an area from box end upset taper to lower part of slip area

USUAL EFFECT

  • String separation
  • Lost time
  • Washout, twist off
  • Pipe loss

PROBABLE CAUSE

  • Cyclic stressing
  • Hydrogen embrittlement
  • Surface notches (corrosion, cuts, etc.)

POSSIBLE CORRECTION

  • Minimize surface notching
  • Avoid excessive rotary speeds
  • Move bottom hole pipe up hole on trips
  • Use shock subs
  • Dampen stress
  • Prevent H2S in flow
  • Use lowest strength pipe where possible
  • Minimize rate of change in hole deviation

CORROSION PITTING

  • General in location

USUAL EFFECT

  • Body wall loss
  • Localized surface notch
  • Stress concentrator(s)

PROBABLE CAUSE

  • Water, CO2, salt, H2S, and stress

POSSIBLE CORRECTION

  • Maintain mud pH above 9.5
  • Plastic coating
  • Inhibitors
  • Oxygen scavenger
  • Clean pipe I.D. & O.D.
  • Monitor with corrosion test rings
  • Dampen stress

SLIP CUTS

  • Located in slip area

USUAL EFFECT

  • Transverse surface notch
  • Stress concentrator(s)

PROBABLE CAUSE

  • Pipe turning in slips
  • Defective slips/bowl, improper slip handling

POSSIBLE CORRECTION

  • Use care when spinning pipe with rotary
  • Improve slip/bowl maintenance
  • Use care while setting slips
  • Use back up tong for make-up and breakout

SLIP AREA MASH

  • Located in slip area

USUAL EFFECT

  • Surface impression
  • Stress concentrator(s)

PROBABLE CAUSE

  • Defective slip component, improper slip handling
  • Excessive connection make-up or breakout)
  • Bending pipe in slips

POSSIBLE CORRECTION

  • Use care while setting slips
  • Consult API-RP7G for maximum height setting of tool joint above slips
  • Improve slip/bowl maintenance

TONG CUTS

  • Usually located near pin end and box end upsets

USUAL EFFECT

  • Multiple surface notches
  • Stress concentrator(s)

PROBABLE CAUSE

  • Tongs placed on pipe, worn tool joints
  • Improper tong jaws, poor handling

POSSIBLE CORRECTION

  • Maintain tool joint diameter
  • Use only correct tong jaws
  • Use sharp tong dies
  • Place tongs only on tool joint

CHAIN CUTS

  • Usually found in an area over and just above pin end upset

USUAL EFFECT

  • Circumferential grooves (notch) at pin and upset area
  • Cold worked metal
  • Stress concentrator(s)

PROBABLE CAUSE

  • Excessive spinning chain slip

POSSIBLE CORRECTION

  • Consider use of power pipe spinner

RUBBER CUT EXTERNAL RING CORROSION

  • Usually found in an area approximately 2' above pin end tool joint

USUAL EFFECT

  • Circumferential groove
  • Stress concentrators

PROBABLE CAUSE

  • Corrosion/erosion at ends of drill pipe/casing protector
  • Poor mud drain/cleaning at protector end

POSSIBLE CORRECTION

  • Clean pipe at ends and under protector
  • Periodically move or remove protector

HAMMER MARKS

  • Usually found on the tube in areas near the pin and box end tool joint

USUAL EFFECT

  • Localized surface notch
  • Cold worked metal

PROBABLE CAUSE

  • Tapping pipe to check fluid level on trip out

POSSIBLE CORRECTION

  • Use brass tipped hammer, tap pipe lightly

SLIP AREA CRUSHING

  • Located in Slip Area

USUAL EFFECT

  • Slip area O.D./ I.D. reduction
  • Longitudinal splits in slip area
  • Body wall thinning

PROBABLE CAUSE

  • Abrupt setting of slips, improper slip size
  • Defective slip/bowl maintenance

POSSIBLE CORRECTION

  • Improve slip/bowl maintenance
  • Stop pipe movement before setting slips
  • Check slip-to-pipe fit
  • Use only correct slip size

NECKING

  • Usually located near either or both upsets

USUAL EFFECT

  • Body wall thinning
  • Reduced pipe O.D./I.D.

PROBABLE CAUSE

  • Stuck pipe, overpull (stretch), excessive hook load

POSSIBLE CORRECTION

  • Avoid sticking pipe, avoid overpull
  • Consult API-RP7G for load limits per pipe class

EXPANSION

  • Usually located above the pin and below the box connections which have been backed off

USUAL EFFECT

  • Expanded O.D./ I.D. split pipe or tool joint

PROBABLE CAUSE

  • Stuck pipe, internal explosion for back off

POSSIBLE CORRECTION

  • Avoid sticking pipe, minimize explosive force
  • Be sure explosive is placed in tool joint area
  • Carefully inspect pipe before re-use

COLLAPSE

  • Usually begins near tube center, often travels toward both ends

USUAL EFFECT

  • String separation
  • Flattens tube, circulation block

PROBABLE CAUSE

  • Excessive O.D. pressure, drill stem test, O.D. wear, I.D. erosion

POSSIBLE CORRECTION

  • Consult API-RP7G collapse charts per pipe in class
  • Minimize O.D. wear, keep pipe straight
  • Prevent I.D. erosion with plastic coating

O.D. WEAR

  • Usually appears in center third of pipe body

USUAL EFFECT

  • Body wall thinning
  • Reduced tensile capacity
  • Reduced cross section
  • Reduced collapse resistance

PROBABLE CAUSE

  • Abrasive formations, crooked pipe, deviated hole, high rotary speeds

POSSIBLE CORRECTION

  • Avoid excessive rotary speeds
  • Minimize rate of change in hole deviation
  • Straighten pipe

I.D. EROSION

  • General location but often appears near upset areas

USUAL EFFECT

  • Body wall thinning
  • Reduced tensile capacity
  • Reduced cross section
  • Reduced collapse resistance

PROBABLE CAUSE

  • High velocity abrasions, sharp sand (solids)
  • Drilling fluid turbulence, general corrosion

POSSIBLE CORRECTION

  • Plastic coating
  • Inhibitors
  • Minimize drilling fluid abrasives
  • Minimize exposure to treating acids

CROOKED PIPE

USUAL EFFECT

  • Accelerated O.D. wear in pipe body and tool joints
  • Vibration
  • High stress level
  • Advanced fatigue

PROBABLE CAUSE

  • Bending in slips, setting tool joint too high above slips
  • Improper tong/ line geometry
  • No back up tong on make-up or breakout
  • Poor transportation handling, dropping pipe on racks
  • Critical rotary speeds, improper drill collar weight
  • Picking up pipe with winch line in center

POSSIBLE CORRECTION

  • Avoid excessive rotary speeds
  • Consult API-RP7G for maximum height setting of tool joint above slips
  • Use both tongs, placed 90 degrees apart
  • Consult API-RP7G for proper make-up torque per tool joint class
  • Minimize breakout and downhole torques
  • Use properly spaced strippers between pipe layers to minimize bending in storage or transit
  • Avoid rough handling when moving pipe
  • Use slings to wench pipe
  • Avoid dropping string
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Tool Joint - Troubleshooting Guide

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WEAR

Thin Shoulders

USUAL EFFECT

  • Reduces torque capacity
  • Belled boxes
  • Reduced shoulder seal area

PROBABLE CAUSE

  • Crooked pipe, abrasive formations
  • High rotary speeds

POSSIBLE CORRECTION

  • Straighten pipe
  • Reduce rotary speeds where possible
  • Apply hardfacing to box end tool joint where possible

BELLED BOXES

USUAL EFFECT

  • Loss of shoulder seal
  • Distorted connection
  • Will not mate properly with another connection
  • Split body

PROBABLE CAUSE

  • Additional down hole makeup
  • Improper make-up torque and thread lubricants
  • Thin tool joints

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Minimize additional downhole make-up
  • Use good quality rotary tool joint compound
  • Maintain tool joint O.D.
  • Re-cut box

STRETCHED PINS

USUAL EFFECT

  • Distorted connection
  • Will not mate properly with another connection
  • Possible pin break

PROBABLE CAUSE

  • Additional downhole make-up
  • Improper make-up torque and thread lubricants

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Recut pin
  • Minimize additional downhole make-up
  • Use good quality rotary tool joint compound

GALLLED THREADS

USUAL EFFECT

  • Lost time
  • Damages mating threads
  • False torque
  • Improper make-up
  • Connection wobble
  • Leaking shoulder seal
  • Washout
  • Pin break
  • Drop string

PROBABLE CAUSE

  • Thread damage, handling without thread protectors
  • Cross threading, worm threads, improper lubrication
  • Dirty connection, defective kelly saver sub

POSSIBLE CORRECTION

  • Handle pipe only with thread protector
  • Use care in stabbing and make-up
  • Re-cut worn threads
  • Clean connections before use
  • Repair or replace kelly saver sub
  • Use good quality rotary tool joint compound

SHOULDER FINS

USUAL EFFECT

  • Lost time
  • False torque
  • Connection wobble
  • Leaking shoulder seal
  • Washout
  • Pin break
  • Drop string
  • Prevents shoulder make-up

PROBABLE CAUSE

  • Mating tool joints with different O.D.'s
  • Handling damage

POSSIBLE CORRECTION

  • Handle pipe only with thread protector
  • Match tool joint O.D.'s if possible
  • Remove fins by refacing and beveling

HEAT CHECK

USUAL EFFECT

  • String separation
  • Lost time
  • Washout
  • Tool joint body cracking

PROBABLE CAUSE

  • High Rotary speeds
  • Rapid cooling, rapid heating due to friction between tool joint and formation, casing, whip stock, etc.

POSSIBLE CORRECTION

  • Reduce rotary speeds through tight areas
  • Minimize tool-joint-to-formation contact

SHOULDER DAMAGE

USUAL EFFECT

  • String separation
  • Lost time
  • Leaking shoulder seal
  • Washout

PROBABLE CAUSE

  • Mis-stabbing connection
  • Handling damage
  • Spinning chain between shoulders, improper pipe jacking

POSSIBLE CORRECTION

  • Use care when tripping pipe
  • Use only pipe jack tool with wide area contact
  • Handle pipe only with thread protector

WASHOUT

USUAL EFFECT

  • Mud pressure loss
  • String separation
  • Lost time
  • Erosion of shoulder (face) seal & threads

PROBABLE CAUSE

  • Insufficient make-up torque
  • Shoulder fins rolled between seals
  • Leaking & damaged shoulder (face) seals
  • Excessive shoulder removal by refacing
  • High spots on shoulder (false make-up torque)
  • Galled threads producing
  • excessive shoulder standoff
  • Stretched pin threads, dirty threads & shoulder
  • Mis-stabbing connection
  • Improper jacking of stands in standback area

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Consult API-RP7G section 12 for maximum shoulder removal by refacing
  • Remove shoulder damage by refacing if possible
  • Re-cut connection
  • Remove shoulder fins by beveling shoulder
  • Keep thread protectors installed while picking, laying down, handling, transporting, or storing pipe
  • Clean threads and shoulder before make-up
  • Use care when tripping pipe
  • Use only pipe jack tool with wide area contact

DRY OR MUDDY CONNECTION

USUAL EFFECT

Leaking shoulder (face) seals

PROBABLE CAUSE

  • Insufficient make-up torque
  • Damaged shoulders (face)

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Consult API-RP7G section 12 for maximum shoulder removal by refacing
  • Remove shoulder damage by refacing if possible
  • Re-cut connection
  • Remove shoulder fins by beveling shoulder
  • Keep thread protectors installed while picking, laying down, handling, transporting, or storing pipe
  • Clean threads and shoulder before make-up
  • Use care when tripping pipe
  • Use only pipe jack tool with wide area contact

GALLED SHOULDER

USUAL EFFECT

  • Loss of shoulder seal
  • Excessive shoulder to shoulder standoff
  • False make-up torque
  • Unstable connection (wobble)

PROBABLE CAUSE

  • Insufficient make-up torque
  • Insufficient lubrication & high spots on shoulders
  • Shoulder fins

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Remove shoulder fins by beveling shoulder
  • Apply rotary tool joint compound shoulders when doping connection
  • Remove high spots by refacing

PIN BREAK

Cup type failure

USUAL EFFECT

  • String separation
  • Lost time
  • Fishing job

PROBABLE CAUSE

  • Improper trip make-up torque
  • Additional down hole make-up
  • Improper type lubricant vs. make-up torque

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Minimize additional downhole make-up
  • Use good quality rotary tool joint compound

PIN BREAK --- SEE MORE

Flat fracture type failure

USUAL EFFECT

  • String separation
  • Lost time
  • Fishing job

PROBABLE CAUSE

  • Shoulder fins
  • Pin wobble, due to insufficient make-up, false torque, stretched threads
  • Fatigue cracking at thread root, galled threads

POSSIBLE CORRECTION

  • Consult API-RP7G charts for proper make-up torque per tool joint class
  • Repair shoulder fins
  • Repair galled threads

PIN BREAK --- SEE MORE

Flat fracture type failure when torque and make-up are known to be satisfactory

USUAL EFFECT

  • String separation
  • Lost time
  • Fishing job

PROBABLE CAUSE

H2S, hydrogen, embrittlement, excessive pin tension

POSSIBLE CORRECTION

  • Reduce stress level if possible
  • Remove string from service for period of time
  • Inspect tool joint threads
  • Control H2S in flow
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Coating Recommendation Form

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Type of Service:

Shut-in Temperature/Pressure:

psi

Flowing Temperature/Pressure:

psi

Corrosive Agents:

%
Units
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