One-Piece BHA Stabilizers for Near-Bit and Drill-String Control

Description

Goldenman Integral Blade Stabilizers are one-piece rotating BHA tools used to maintain borehole gauge, centralize Drill Collars and other bottom-hole-assembly components, control lateral movement and support predictable directional response.

The stabilizer body and blades are manufactured as one continuous load-bearing component. This eliminates welded blade joints and replaceable sleeves from the primary structure, reducing the risk of blade separation or loose components remaining in the well.

Goldenman supplies:

• Spiral Integral Blade Stabilizers
• Straight Integral Blade Stabilizers
• Near-Bit Integral Blade Stabilizers
• String Integral Blade Stabilizers
• Three-Blade Stabilizers
• Four-Blade Stabilizers
• Alloy-Steel Stabilizers
• Non-Magnetic Integral Blade Stabilizers
• Open-Spiral Blade Configurations
• Full-Wrap Blade Configurations
• Full-Gauge Stabilizers
• Under-Gauge Stabilizers
• Tungsten-Carbide Hardfaced Stabilizers
• Casing-Friendly Wear-Surface Configurations
• Stabilizers with Float-Valve Bores
• Custom Box × Box, Box × Pin and Pin × Box Connections

The published Goldenman range covers stabilizer working outside diameters from 3-3/4 to 36 inches, with separate Near-Bit and String Stabilizer lengths.

Product Short Description

Goldenman Integral Blade Stabilizers are machined from high-strength alloy-steel or non-magnetic material as a one-piece tool.

Three or four straight or spiral blades contact the wellbore and control the radial position of the BHA. The stabilizer helps keep Drill Collars, Downhole Motors, MWD tools and other components away from direct borehole-wall contact.

Correctly positioned stabilizers can help:

• Maintain nominal hole gauge
• Improve bit and BHA stability
• Reduce lateral vibration
• Reduce drill-string whirl
• Reduce borehole spiraling and tortuosity
• Improve weight transfer to the bit
• Control build, hold or drop tendency
• Reduce localized Drill Collar wear
• Improve the probability of running casing to depth
• Reduce differential-sticking exposure by limiting broad BHA wall contact

The finished stabilizer is selected according to hole size, blade OD, body OD, internal bore, blade configuration, hardfacing, BHA position, connections, formation and drilling environment.

Product Highlights

• One-piece body and blade construction
• No welded blade-to-body joints
• No replaceable sleeve in the primary load path
• Standard working OD from 3-3/4 to 36 in
• Spiral and straight blade configurations
• Near-Bit and String Stabilizer designs
• Three- and four-blade options
• Alloy-steel and non-magnetic materials
• Full-gauge and under-gauge designs
• Open and high-wrap spiral configurations
• High-strength forged alloy-steel body
• AISI 4145H Modified material options
• Non-magnetic austenitic alloy options
• Tungsten-carbide wear protection
• Casing-friendly hardbanding options
• Replaceable wear restoration by shop redressing
• Large internal flow bore
• Open flow channels between blades
• Reduced restriction to drilling-fluid circulation
• NC and API Regular connection options
• Box × Box, Box × Pin and Pin × Box configurations
• Stress-relief grooves and borebacks available
• Float-valve bore available
• Material and heat-number traceability
• Mechanical-property verification
• Full-body ultrasonic inspection
• Magnetic-particle inspection
• Thread-gauge inspection
• Blade-OD and concentricity inspection
• Hardfacing inspection
• Complete manufacturing and inspection records

General Technical Specifications

Parameter	Available Configuration
Product	Integral Blade Stabilizer
Abbreviation	IBS
Product category	Rotary Drill Stem Element / BHA Stabilizer
Standard working OD	3-3/4–36 in
Main applications	Near-Bit and String Stabilization
Blade configurations	Spiral or straight
Standard blade quantity	3 or 4
Blade construction	Integral with tool body
Gauge configuration	Full gauge, under gauge or custom
Spiral coverage	Open spiral or project-specific wrap
Main body material	High-strength heat-treated alloy steel
Non-magnetic option	Available
Standard alloy option	AISI 4145H Modified or qualified equivalent
Internal bore	Size dependent
Wear protection	Carbide inserts, crushed carbide or casing-friendly hardband
Connections	NC, REG and approved custom rotary-shouldered connections
Connection arrangement	Box × Box, Box × Pin or Pin × Box
Product standard	API Spec 7-1 where specified
Connection standard	API Spec 7-2 where applicable
Special features	Float bore, SRG, boreback and custom fishing neck
Drilling fluids	WBM, OBM, SBM and compatible drilling fluids
Service	Vertical, directional, horizontal and extended-reach wells
Inspection	Material, UT, MPI, dimensional, thread and hardfacing inspection
Supply	Complete stabilizer and redressing service

Published Goldenman Size Range

Stabilizer OD	Metric OD	Body OD	Tool ID	Fishing-Neck Length	Blade Crown Length	Blade Taper	String-Type Length	Near-Bit Length	String / Near-Bit Connection
3-3/4 in	95.3 mm	79.4 mm	31.8 mm	660 mm	254 mm	30° / 15°	1,480 mm	1,370 mm	NC23 / 2-3/8 REG
4-1/2 in	114.3 mm	88.9 mm	38.1 mm	660 mm	254 mm	30° / 15°	1,500 mm	1,400 mm	NC26 / 2-3/8 REG
6 in	152.4 mm	120.7 mm	50.8 mm	762 mm	305 mm	30°	1,760 mm	1,600 mm	NC38 / 3-1/2 REG
7-1/2 in	190.5 mm	165.1 mm	71.4 mm	762 mm	406 mm	30° / 30°	1,860 mm	1,700 mm	NC46 / 4-1/2 REG
8 in	203.2 mm	171.5 mm	71.4 mm	762 mm	406 mm	30° / 30°	1,860 mm	1,700 mm	NC50 / 4-1/2 REG
8-1/2 in	215.9 mm	171.5 mm	71.4 mm	762 mm	406 mm	30° / 30°	1,880 mm	1,730 mm	NC50 / 4-1/2 REG
9-1/2 in	241.3 mm	171.5 mm	71.4 mm	762 mm	406 mm	30° / 30°	1,930 mm	1,780 mm	NC50 / 4-1/2 REG
12-1/4 in	311.2 mm	203.2 mm	71.4 mm	762 mm	457 mm	30° / 30°	2,030 mm	1,880 mm	6-5/8 REG / 6-5/8 REG
14-3/4 in	374.7 mm	203.2 mm	71.4 mm	762 mm	457 mm	30° / 30°	2,140 mm	1,990 mm	6-5/8 REG / 6-5/8 REG
16 in	406.4 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 30°	2,180 mm	2,030 mm	7-5/8 REG / 7-5/8 REG
17-1/2 in	444.5 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 30°	2,260 mm	2,110 mm	7-5/8 REG / 7-5/8 REG
20 in	508.0 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,200 mm	2,050 mm	7-5/8 REG / 7-5/8 REG
22 in	558.8 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,250 mm	2,100 mm	7-5/8 REG / 7-5/8 REG
24 in	609.6 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,310 mm	2,160 mm	7-5/8 REG / 7-5/8 REG
26 in	660.4 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,360 mm	2,210 mm	7-5/8 REG / 7-5/8 REG
28 in	711.2 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,410 mm	2,260 mm	7-5/8 REG / 7-5/8 REG
30 in	762.0 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,460 mm	2,310 mm	7-5/8 REG / 7-5/8 REG
32 in	812.8 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,510 mm	2,360 mm	7-5/8 REG / 7-5/8 REG
34 in	863.6 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,560 mm	2,410 mm	7-5/8 REG / 7-5/8 REG
36 in	914.4 mm	241.3 mm	76.2 mm	762 mm	508 mm	30° / 45°	2,610 mm	2,460 mm	7-5/8 REG / 7-5/8 REG

Dimensions shown represent the published standard series. Final body dimensions, bore, blade geometry, fishing-neck length and connections are controlled by the approved manufacturing drawing.

What Is an Integral Blade Stabilizer?

An Integral Blade Stabilizer is a fixed-gauge rotating drill-string tool whose stabilizing blades are machined as part of the main body.

The tool is installed within the BHA to control lateral movement and maintain the designed radial position of:

• Drill Bits
• Drill Collars
• Downhole Motors
• Rotary Steerable Systems
• MWD Tools
• LWD Tools
• Non-Magnetic Drill Collars
• Heavy Weight Drill Pipe
• Coring Assemblies

Unlike a welded-blade stabilizer, the blades are not attached to the body by structural welding.

Unlike a sleeve stabilizer, the gauge section is not a separate replaceable sleeve.

Operating Principle

The stabilizer blades contact or approach the borehole wall while the BHA rotates.

The blade OD creates defined radial support points around the assembly.

These support points help:

• Limit lateral BHA displacement
• Control bending distribution
• Reduce direct Drill Collar contact
• Maintain bit alignment
• Control the effective fulcrum position
• Support the planned directional tendency
• Reduce local contact pressure on other BHA components

The stabilizer itself does not steer independently. Its effect is created by its position, gauge, blade geometry and interaction with the complete BHA.

One-Piece Construction

The stabilizer is manufactured from one solid forged or bar-stock body.

The body and blades form one continuous component.

Advantages include:

• No blade-to-body structural weld
• No sleeve-to-mandrel connection
• High torsional continuity
• High axial-load capacity
• Reduced number of downhole components
• Reduced risk of blade detachment
• Stable blade alignment
• Controlled concentricity
• Efficient nondestructive inspection
• Suitability for high-load rotary drilling

The integral construction is particularly useful where shock, vibration, high rotary torque or long drilling intervals increase the demands on the stabilizer.

Spiral Integral Blade Stabilizer

A Spiral Integral Blade Stabilizer uses blades that wrap helically around the body.

The spiral profile provides:

• Progressive contact with the wellbore
• Smoother entry into borehole restrictions
• Reduced abrupt blade impact
• Continuous or near-continuous circumferential support
• Open helical flow channels
• Improved drilling-fluid and cuttings bypass
• Reduced local concentration of wall contact
• Stable rotation in deviated wellbores

Spiral blades are commonly selected for directional, horizontal and abrasive drilling applications.

Straight Integral Blade Stabilizer

A Straight Integral Blade Stabilizer uses blades running parallel to the tool axis.

Straight blades provide:

• Direct longitudinal contact
• Simple gauge measurement
• Large open flow channels
• Efficient solids bypass
• Strong radial stabilization
• Straightforward hardfacing repair
• Reliable performance in vertical and low-angle wells

Straight blades can also be selected where the operator prefers reduced spiral reaction or simpler redressing.

Spiral vs Straight Blades

Selection Factor	Spiral Blades	Straight Blades
Borehole contact	Progressive and distributed	Direct longitudinal contact
Flow path	Helical channels	Straight axial channels
Entry into restriction	Smoother progressive contact	More direct contact
Torque behavior	Usually smoother	Formation and side-load dependent
Hole-wall support	Broad circumferential support	Concentrated at blade positions
Redressing	Geometry-sensitive	Relatively straightforward
Common application	Directional and horizontal wells	Vertical and general drilling
Cuttings bypass	Helical	Direct axial

The correct blade style depends on formation, BHA design, torque limits and hole-cleaning requirements.

Three-Blade Stabilizer

A Three-Blade Stabilizer provides three radial contact points.

Advantages include:

• Large flow channels
• Reduced blade contact area
• Lower risk of solids packing
• Lower weight
• Good circumferential support
• Reduced hydraulic restriction
• Efficient use in sticky or high-solids formations

Three-blade spiral designs are commonly used where maximum flow area and reduced torque are priorities.

Four-Blade Stabilizer

A Four-Blade Stabilizer provides four radial contact points.

Advantages include:

• Increased contact distribution
• Increased radial support
• Reduced unsupported circumference
• Stable BHA positioning
• Increased wear surface
• Improved support under high lateral loading

Four-blade models can create more contact area and must be assessed for torque, drag and cuttings bypass.

Three vs Four Blades

Selection Factor	Three Blades	Four Blades
Annular flow area	Larger	Smaller for equivalent body geometry
Contact area	Lower	Higher
Radial support points	Three	Four
Solids bypass	High	Design dependent
Torque and drag	Often lower	Can be higher under side load
Wear distribution	Three main surfaces	Four main surfaces
Main use	High-flow and reduced-contact applications	Increased support and contact distribution

Near-Bit Integral Blade Stabilizer

A Near-Bit Stabilizer is installed immediately above or close to the drill bit.

It helps:

• Stabilize the bit
• Reduce bit whirl
• Control lateral bit movement
• Maintain hole size close to the bit
• Reduce borehole spiraling
• Improve bit-to-formation engagement
• Influence build, hold or drop tendency
• Improve directional response
• Protect the lower Drill Collar from wall contact

Near-Bit models normally use a shorter overall length than equivalent String Stabilizers.

The lower connection is selected to match the bit, Bit Sub, Downhole Motor or adjacent BHA component.

String Integral Blade Stabilizer

A String Stabilizer is installed farther above the bit within the BHA.

Typical locations include:

• Between Drill Collars
• Above a Downhole Motor
• Above or below MWD and LWD tools
• Within a packed BHA
• In a tangent-section BHA
• Near a known high-contact interval
• Between Non-Magnetic Drill Collars

A String Stabilizer helps:

• Centralize the Drill Collar section
• Reduce BHA bending
• Reduce lateral vibration
• Improve weight transfer
• Control directional tendency
• Protect sensitive BHA tools
• Reduce Drill Collar wear

Near-Bit vs String Stabilizer

Selection Factor	Near-Bit Stabilizer	String Stabilizer
Position	Immediately above or close to bit	Higher in the BHA
Main influence	Bit stability and lower-BHA geometry	Drill-string and collar stabilization
Typical length	Shorter	Longer
Lower connection	Matched to bit or lower BHA	Matched to Drill Collar string
Directional influence	Strong near-bit effect	Depends on distance from bit
Gauge protection	Immediate	Conditions hole behind bit
Application	Build, hold, drop and bit stability	Packed, tangent and string control

Full-Gauge Stabilizer

A Full-Gauge Stabilizer has a blade OD close to the nominal bit or finished-hole diameter.

Full-gauge designs provide:

• Strong radial support
• Controlled BHA position
• Reduced Drill Collar wall contact
• Improved hole-size consistency
• Predictable BHA response

The final OD is normally selected with a defined clearance below bit gauge.

The required clearance depends on:

• Hole size
• Formation stability
• Hole enlargement
• BHA position
• Directional requirement
• Expected gauge wear
• Tripping-clearance requirement
• Operator practice

Under-Gauge Stabilizer

An Under-Gauge Stabilizer has a blade OD intentionally smaller than nominal hole size.

It is selected to:

• Reduce torque and drag
• Provide additional tripping clearance
• Reduce the risk of sticking
• Allow controlled directional response
• Compensate for expected hole conditions
• Reduce contact in unstable formations

Excessive under-gauge clearance reduces stabilizing effectiveness.

The selected OD should therefore be based on BHA modeling rather than a universal fixed reduction.

Open-Spiral Design

An open-spiral stabilizer uses separated spiral blades with substantial flow channels between them.

It provides:

• Large bypass area
• Strong cuttings transport
• Reduced packoff risk
• Reduced hydraulic restriction
• Lower contact area
• Easier cleaning and inspection

This design is commonly selected for sticky shale, high-solids drilling fluids and sections where hole cleaning is critical.

High-Wrap and Full-Wrap Designs

Higher-wrap blade configurations increase circumferential wellbore contact.

They can provide:

• Increased radial support
• More continuous hole-wall contact
• Improved gauge retention
• Greater wear surface
• Reduced local blade loading

The increased contact area can also increase torque and sensitivity to cuttings packing.

The blade wrap should therefore be matched to formation, side load and hydraulic requirements.

Build-Angle BHA

A build-angle or fulcrum BHA normally uses a Near-Bit Stabilizer with selected spacing to the next major contact point.

The assembly uses BHA bending to create a build tendency.

Build rate is affected by:

• Stabilizer gauge
• Bit-to-stabilizer distance
• Stabilizer spacing
• Drill Collar stiffness
• Motor bend setting
• Weight on bit
• Formation response
• Rotary speed
• Hole inclination

The stabilizer does not independently guarantee a specific build rate.

Hold-Angle BHA

A packed BHA uses multiple stabilizers to resist bending and maintain inclination.

It can provide:

• Stable directional response
• Reduced unwanted dogleg
• Reduced borehole tortuosity
• Improved hole quality
• Reduced BHA vibration
• Improved casing-running conditions

The gauge and spacing of every stabilizer must be included in the BHA model.

Drop-Angle BHA

A pendulum BHA positions the first major stabilizing point farther above the bit.

The unsupported lower Drill Collar section uses gravity and bending to create a drop tendency.

Stabilizer position, gauge and Drill Collar stiffness determine the strength of the pendulum effect.

Vertical-Well Applications

In vertical drilling, Integral Blade Stabilizers help:

• Control hole deviation
• Reduce bit whirl
• Maintain straight-hole tendency
• Reduce Drill Collar wall contact
• Reduce borehole spiraling
• Improve weight transfer
• Maintain hole gauge

Straight or spiral configurations can be selected according to formation and hydraulic requirements.

Directional-Well Applications

Directional drilling creates intentional BHA side force and bending.

Stabilizer selection helps control:

• Build rate
• Hold tendency
• Drop tendency
• Toolface response
• BHA contact force
• Lateral vibration
• Borehole tortuosity
• Dogleg quality

Near-Bit and String Stabilizers should be positioned according to the planned directional model.

Horizontal-Well Applications

Horizontal wells create high low-side contact force.

Integral Blade Stabilizers can help:

• Support the BHA above the low side
• Reduce Drill Collar contact
• Improve weight transfer
• Reduce lateral vibration
• Reduce local wear
• Maintain directional stability
• Improve the effective borehole profile

The fixed working OD can also create high torque or sticking risk if cuttings accumulate around the stabilizer.

Horizontal applications require careful control of:

• Blade OD
• Flow area
• Cuttings transport
• Blade contact area
• BHA placement
• Hole enlargement
• Tripping strategy

Extended-Reach Applications

Extended-reach wells combine long contact intervals, high torque and high drag.

A properly selected IBS can support:

• BHA stability
• Improved weight transfer
• Reduced lateral tool movement
• Protection of directional tools
• Improved hole quality

Applications with severe cuttings accumulation or repeated stabilizer sticking can require an under-gauge, roller, collapsible or variable-gauge stabilizer instead of a conventional full-gauge IBS.

Formation Selection

Soft and Sticky Formations

Soft shale and sticky clay can pack around wide blades.

Recommended design considerations include:

• Three-blade configuration
• Open spiral
• Large flow channels
• Reduced contact area
• Smooth hardfacing transition
• Controlled under-gauge clearance

Medium-Hard Formations

Medium formations commonly use:

• Three or four blades
• Spiral or straight geometry
• Standard carbide hardfacing
• Full-gauge or slightly under-gauge OD

Hard and Abrasive Formations

Hard formations require:

• High-wear hardfacing
• Carbide inserts or crushed carbide
• Increased wear-surface coverage
• Stable blade gauge
• High-strength integral body
• Frequent gauge inspection

Alloy-Steel Stabilizer

Standard alloy stabilizers can be manufactured from AISI 4145H Modified or an approved equivalent material.

The material provides:

• High tensile strength
• High torsional capacity
• Impact toughness
• Fatigue resistance
• Stable heat-treatment response
• Resistance to drilling shock and vibration
• Reliable connection machining

The body is quenched and tempered before final machining and inspection.

Non-Magnetic Integral Blade Stabilizer

A Non-Magnetic Stabilizer is used close to directional survey equipment where magnetic interference must be minimized.

Applications include:

• MWD Assemblies
• LWD Assemblies
• Magnetometer-Based Survey Tools
• Rotary Steerable Systems
• Geosteering BHAs
• Non-Magnetic Drill Collar Assemblies

Non-magnetic configurations require control of:

• Magnetic permeability
• Local magnetic field
• Material cleanliness
• Mechanical properties
• Surface hardening process
• Heat input during wear-surface application
• Final magnetic inspection

Hardfacing procedures for non-magnetic materials must avoid creating unacceptable magnetic hot spots or damaging the base material.

Standard vs Non-Magnetic Material

Selection Factor	Alloy-Steel IBS	Non-Magnetic IBS
Main purpose	General drilling stabilization	Magnetic isolation near survey tools
Material	Heat-treated alloy steel	Qualified non-magnetic alloy
Magnetic permeability	Conventional steel behavior	Controlled low permeability
Magnetic inspection	Normally not primary	Required
Cost	Lower	Higher
Hardfacing procedure	Conventional qualified process	Low-magnetism process required
Main BHA location	General Near-Bit or String position	Near MWD, LWD or survey instruments

Hardfacing and Wear Protection

The blade surface receives wear protection to maintain stabilizer gauge in abrasive drilling conditions.

Available wear-surface systems can include:

• Tungsten-carbide inserts
• Crushed tungsten-carbide hardfacing
• Carbide tiles
• Carbide blocks
• Sintered carbide buttons
• Casing-friendly hardbanding
• Non-magnetic-compatible wear overlays
• Project-specific hardfacing patterns

The correct system depends on:

• Formation abrasiveness
• Hole section length
• Rotary speed
• Stabilizer side load
• Casing-contact risk
• Required redressing method
• Base material
• Maximum permitted gauge wear

Tungsten-Carbide Inserts

Carbide inserts provide localized high-wear protection.

Inspection includes:

• Insert material grade
• Insert dimensions
• Hole dimensions
• Interference fit
• Insert projection
• Insert pattern
• Missing or cracked inserts
• Blade-base cracking

Crushed-Carbide Hardfacing

Crushed tungsten carbide is deposited in a metallic matrix over selected blade surfaces.

It provides:

• High abrasion resistance
• Broad surface protection
• Repairability
• Flexible coverage pattern
• Protection of leading and gauge edges

Quality control covers:

• Coverage
• Thickness
• Carbide distribution
• Bond integrity
• Porosity
• Cracking
• Final machined OD

Casing-Friendly Wear Surface

Where the stabilizer can contact casing, the wear surface should balance:

• Stabilizer wear resistance
• Casing-wear control
• Resistance to cracking
• Resistance to spalling
• Surface smoothness
• Metal-to-metal friction

Aggressive exposed carbide should not be used in cased-hole rotation without reviewing casing-wear risk.

Blade Gauge Selection

The stabilizer blade OD is selected from:

• Bit diameter
• Required finished-hole diameter
• Stabilizer BHA position
• Full-gauge or under-gauge strategy
• Hole enlargement tendency
• Expected wear
• Tripping clearance
• Directional response
• Formation stability
• Maximum permissible torque

The blade OD must be stated on the approved drawing and final inspection report.

Body OD and Flow Area

Body OD affects:

• Tool strength
• Internal bore
• Annular bypass
• Cutter and blade support
• Fishing clearance
• Hydraulic pressure loss
• Cuttings transport

A larger body provides increased structural section but reduces annular flow area.

Internal Bore

The tool ID is selected according to:

• Required drilling-fluid flow rate
• Bit hydraulic requirement
• MWD and LWD flow requirement
• Float-valve requirement
• Drop-ball or activation-device passage
• Connection size
• Structural strength
• Pressure loss

The bore must remain aligned through the connections and central body.

Float-Valve Bore

Selected stabilizers can be bored to accept a Float Valve or related internal component.

The quotation should identify:

• Float-valve type
• Float-valve size
• Bore diameter
• Seat profile
• Retainer arrangement
• Flow direction
• Access for inspection and replacement

Rotary-Shouldered Connections

Available connection families include:

• NC23
• NC26
• NC31
• NC38
• NC40
• NC46
• NC50
• 2-3/8 REG
• 3-1/2 REG
• 4-1/2 REG
• 6-5/8 REG
• 7-5/8 REG
• Customer-specified rotary-shouldered connections

Connection availability depends on:

• Tool body OD
• Internal bore
• Tensile requirement
• Torsional requirement
• BHA compatibility
• Near-Bit or String location

Connection Arrangements

Goldenman can supply:

• Box × Box
• Box × Pin
• Pin × Box
• Project-specific crossover arrangements

Near-Bit tools commonly use a lower connection matched to the bit or Bit Sub.

String Stabilizers normally use connections matched to adjacent Drill Collars or BHA components.

Connection Inspection

Rotary-shouldered connection inspection includes:

• Thread form
• Taper
• Lead
• Pitch diameter
• Thread height
• Root and crest condition
• Pin nose
• Box counterbore
• Shoulder flatness
• Shoulder perpendicularity
• Surface finish
• Gauge standoff
• Connection concentricity

Stress-Relief Features

Pin Stress-Relief Grooves and box borebacks are available according to connection geometry and fatigue requirements.

These features can reduce stress concentration near the last engaged thread during:

• High bending
• Directional drilling
• Torsional vibration
• Repeated rotary loading
• High dogleg severity

The final geometry must remain consistent with connection-strength requirements.

Integral Blade Stabilizer vs Welded Blade Stabilizer

Integral Blade Stabilizer	Welded Blade Stabilizer
Blades machined as part of body	Blades welded to body
No structural blade weld	Contains blade-to-body welds
High structural continuity	Flexible manufacturing geometry
High initial manufacturing cost	Often lower manufacturing cost
Strong high-load capability	Suitable for many conventional applications
Redressing limited by body condition	Blades can sometimes be replaced
Preferred for demanding BHA service	Useful for custom and economical designs

Integral Blade Stabilizer vs Sleeve Stabilizer

Integral Blade Stabilizer	Replaceable Sleeve Stabilizer
Gauge section integral with body	Gauge section installed as a sleeve
No sleeve-retention mechanism	Requires sleeve retention
High structural continuity	One mandrel can use different sleeves
Complete body redressed when worn	Worn sleeve can be replaced
Higher inventory by hole size	Reduced mandrel inventory
Lower risk of loose sleeve components	More internal components

Integral Blade Stabilizer vs Roller Reamer

Integral Blade Stabilizer	Roller Reamer
Fixed blades slide against wellbore	Rollers rotate against wellbore
Main function is stabilization	Stabilizes and actively conditions hole
No moving cutter parts	Contains rollers, axles and bearings
Simple inspection and maintenance	Requires cutter and bearing maintenance
Can generate higher sliding contact	Rolling contact can reduce parasitic torque
Hardfacing maintains gauge	Roller teeth or buttons condition formation

The Roller Reamer page should target hole conditioning and active reaming, while this page should target fixed-gauge BHA stabilization.

Integral Blade Stabilizer vs Hydraulic Variable-Gauge Stabilizer

Integral Blade Stabilizer	Hydraulic Variable-Gauge Stabilizer
Fixed working OD	Hydraulically changing OD
Solid one-piece body and blades	Contains moving support heads and seals
Same OD during drilling and tripping	Can retract during pump-off condition
Low mechanical complexity	More complex hydraulic maintenance
Suitable for conventional BHA stabilization	Suitable where trip clearance is critical
No activation-pressure requirement	Requires differential pressure

Integral Blade Stabilizer vs Non-Rotating Stabilizer

Integral Blade Stabilizer	Non-Rotating Stabilizer
Rotates with drill string	Outer sleeve can remain relatively stationary
Integral steel blades	Sleeve, elastomer or bearing-supported contact section
Transmits full rotary torque	Designed to reduce rotating wall contact
Fixed solid construction	Contains moving or flexible components
General drilling stabilization	Specialized torque, wear or intervention applications

Pre-Run Inspection

Before running:

1. Verify the stabilizer OD.
2. Confirm Near-Bit or String configuration.
3. Confirm three- or four-blade design.
4. Verify spiral or straight blades.
5. Confirm top and bottom connections.
6. Verify Box and Pin orientation.
7. Inspect the body for impact or corrosion.
8. Measure blade gauge.
9. Inspect gauge-edge wear.
10. Inspect hardfacing and carbide inserts.
11. Inspect the internal bore.
12. Inspect the fishing neck.
13. Gauge the rotary-shouldered connections.
14. Inspect sealing shoulders.
15. Confirm free passage through every known restriction.
16. Record the serial number and inspection results.

BHA Makeup

1. Clean the stabilizer connections.
2. Clean the adjacent BHA connections.
3. Inspect pin and box shoulders.
4. Apply approved rotary-shouldered thread compound.
5. Align the connections.
6. Start makeup without cross-threading.
7. Apply the specified makeup torque.
8. Record the stabilizer position.
9. Confirm unrestricted internal circulation.
10. Update the final BHA tally and drawing.

Drilling Operation

During drilling, monitor:

• Surface and downhole torque
• Weight on bit
• Rate of penetration
• Rotary speed
• Standpipe pressure
• Stick-slip
• Lateral vibration
• Whirl
• Directional response
• Toolface stability
• Hole cleaning
• Cuttings returns
• Drag during connections

Abnormal torque or vibration can indicate:

• Excessive blade contact
• Stabilizer packing
• Severe side load
• Gauge wear
• Formation transition
• Inadequate hole cleaning
• BHA resonance
• Connection damage

Tripping and Reaming

The tool should be moved through restrictions at a controlled rate.

Monitor:

• Overpull
• Set-down weight
• Pump pressure
• Torque
• Restriction depth
• Cuttings return

A conventional fixed-gauge Integral Blade Stabilizer should not be forced through a restriction smaller than its measured OD.

Backreaming should follow the approved BHA and operating program.

Common Failure Modes

Excessive Blade Wear

Possible causes include:

• Abrasive formation
• High side load
• Excessive rotary speed
• Long rotating interval
• Inadequate hardfacing
• Carbide loss
• Poor hole cleaning

Stabilizer Becomes Under Gauge

Possible causes include:

• Hardfacing wear
• Carbide insert loss
• Gauge-edge damage
• Incorrect redressing
• Extended abrasive service
• Tool-body erosion

Excessive Torque

Possible causes include:

• Full-gauge OD in a tight hole
• Cuttings packed around blades
• High BHA side force
• Large blade contact area
• Damaged hardfacing
• Hole collapse
• Inadequate annular flow area

Differential Sticking

Possible causes include:

• High overbalance pressure
• Permeable formation
• Thick filter cake
• Stationary BHA
• Broad stabilizer or collar contact
• Poor hole cleaning

A stabilizer can reduce broad Drill Collar contact but cannot eliminate differential-sticking risk.

Blade Cracking

Possible causes include:

• Material defect
• Improper heat treatment
• Severe impact
• Excessive bending
• Hardfacing heat damage
• Stress concentration
• Previous overload

Hardfacing Cracking or Spalling

Possible causes include:

• Excessive heat input
• Poor surface preparation
• Incorrect carbide distribution
• Severe impact
• Incompatible base and overlay materials
• Repeated redressing
• Insufficient inspection

Connection Fatigue

Possible causes include:

• Incorrect makeup torque
• Worn shoulder
• Thread damage
• High dogleg severity
• Repeated bending
• Stick-slip
• Torsional vibration
• Excessive recutting

Solids Packing

Possible causes include:

• Insufficient blade flow area
• Sticky formation
• High solids loading
• Low annular velocity
• Inadequate circulation
• Excessive blade wrap
• Cuttings-bed accumulation

Post-Run Inspection

After each run:

• Clean the complete stabilizer
• Remove solids from blade channels
• Measure blade OD
• Record gauge loss
• Inspect all hardfacing
• Inspect carbide inserts
• Inspect leading and trailing tapers
• Inspect the tool body
• Inspect the fishing neck
• Inspect the internal bore
• Inspect top and bottom connections
• Perform MPI on critical areas
• Review drilling vibration and overload records
• Determine redress or retirement status
• Apply corrosion protection
• Install thread protectors

Redressing

A worn stabilizer can be redressed when sufficient base material and structural integrity remain.

A redressing process can include:

1. Remove damaged hardfacing.
2. Inspect the blade base.
3. Perform NDE on the affected areas.
4. Restore blade geometry.
5. Apply qualified wear-surface material.
6. Control heat input.
7. Machine or grind to final OD.
8. Inspect hardfacing bond and coverage.
9. Verify blade concentricity.
10. Complete final MPI.
11. Issue a redress inspection record.

Redressing must not conceal cracks, excessive blade-base loss or body damage.

Manufacturing Process

Goldenman manufacturing includes:

1. Alloy-steel or non-magnetic material verification
2. Heat-number assignment
3. Forging ultrasonic inspection
4. Rough body machining
5. Quenching and tempering where applicable
6. Mechanical-property testing
7. Internal-bore machining
8. Fishing-neck machining
9. Blade rough machining
10. Spiral or straight blade profiling
11. Blade-crown machining
12. Leading- and trailing-taper machining
13. Top and bottom connection machining
14. Thread gauging
15. Stress-relief groove machining where required
16. Hardfacing or carbide application
17. Final blade-OD finishing
18. Dimensional inspection
19. Blade-concentricity inspection
20. Full-body UT
21. Magnetic-particle inspection
22. Magnetic-property testing for non-magnetic tools
23. Final visual inspection
24. Product marking
25. Surface protection
26. Documentation review
27. Export packaging

Quality Control and Testing

Goldenman quality control can include:

• Raw-material certificate verification
• Chemical-composition testing
• Heat-number traceability
• Heat-treatment monitoring
• Yield-strength testing
• Tensile-strength testing
• Elongation testing
• Impact testing
• Body-hardness inspection
• Full-body ultrasonic inspection
• Magnetic-particle inspection
• Liquid-penetrant inspection where applicable
• Magnetic-permeability testing
• Magnetic-field inspection
• Blade-OD inspection
• Body-OD inspection
• Internal-bore inspection
• Fishing-neck inspection
• Blade-crown-length inspection
• Blade-taper inspection
• Overall-length inspection
• Concentricity inspection
• Thread-gauge inspection
• Shoulder inspection
• Hardfacing coverage inspection
• Carbide-insert inspection
• Final visual inspection

API Spec 7-1 Positioning

API Spec 7-1 provides technical delivery requirements for Stabilizers and other defined Rotary Drill Stem Elements.

Applicable requirements can include:

• Materials
• Heat treatment
• Mechanical properties
• Dimensions
• Nondestructive examination
• Workmanship
• Traceability
• Marking
• Documentation

API Spec 7-1 does not independently establish:

• Guaranteed torque reduction
• Guaranteed vibration reduction
• Directional build rate
• Maximum drilling interval
• Hardfacing service life
• Maximum operating RPM
• Differential-sticking prevention
• Formation-specific performance

These values depend on the tool design, BHA configuration and operating conditions.

API Spec 7-2 Positioning

API Spec 7-2 applies to qualifying NC and REG rotary-shouldered connections.

It covers:

• Thread dimensions
• Connection dimensions
• Gauges
• Gauging practices
• Inspection methods
• Recut connections
• Selected finishing requirements

API Spec 7-2 connection conformity does not independently certify the blade geometry, hardfacing or stabilizing performance of the complete tool.

Product Marking

Each stabilizer can be permanently marked with:

• Goldenman identification
• Integral Blade Stabilizer
• Near-Bit or String type
• Working OD
• Body OD
• Tool ID
• Blade quantity
• Spiral or straight configuration
• Top connection
• Bottom connection
• Material grade
• Heat number
• Serial number
• Manufacturing date
• Standard reference
• Non-magnetic identification where applicable

Product Documentation

Available documentation includes:

• Certificate of Conformity
• Product datasheet
• General assembly drawing
• BHA dimensional drawing
• Material Test Certificate
• EN 10204 3.1 certificate
• Chemical-composition report
• Heat-treatment record
• Mechanical-property report
• Hardness report
• Impact-test report
• Ultrasonic-inspection report
• Magnetic-particle-inspection report
• Magnetic-permeability report
• Magnetic-field inspection report
• Thread-gauge inspection report
• Dimensional inspection report
• Blade-OD inspection report
• Concentricity report
• Hardfacing inspection report
• Carbide-insert report
• Material and component traceability list
• Makeup-torque recommendation
• Operation and maintenance manual
• Redressing criteria
• Packing list
• Third-party inspection report

Frequently Asked Questions

What product is shown on this page?

This page covers Goldenman Integral Blade Stabilizers for Near-Bit and String BHA applications.

What is an Integral Blade Stabilizer?

It is a one-piece rotating stabilizer whose blades are machined as part of the main tool body.

What is the standard size range?

The published Goldenman range covers working ODs from 3-3/4 to 36 inches.

Are spiral and straight blades available?

Yes.

Goldenman supplies both Spiral and Straight Integral Blade Stabilizers.

How many blades are available?

Three- and four-blade designs are standard configurations.

What is a Near-Bit Stabilizer?

It is installed immediately above or close to the bit to stabilize the lower BHA and influence bit behavior.

What is a String Stabilizer?

It is positioned higher in the BHA to centralize Drill Collars and control bending, vibration and directional response.

What is the difference between Near-Bit and String models?

Near-Bit Stabilizers are generally shorter and use a lower connection matched to the bit-side assembly.

String Stabilizers are generally longer and connect between Drill Collars or other BHA components.

Is the stabilizer full gauge?

Full-gauge, slightly under-gauge and custom blade ODs are available.

The required OD must be stated in the purchase order.

Does the stabilizer enlarge the hole?

Its principal function is BHA stabilization and gauge maintenance.

It is not intended to perform substantial hole enlargement like an Underreamer or Hole Opener.

What is the difference between an IBS and a Roller Reamer?

An IBS uses fixed integral blades.

A Roller Reamer uses rotating cutters and provides more active hole conditioning.

What is the difference between an IBS and a Variable-Gauge Stabilizer?

An IBS has a fixed working OD.

A Variable-Gauge Stabilizer uses hydraulic or mechanical components to change its operating diameter.

Which blade style is suitable for directional wells?

Spiral blades are commonly selected for directional and horizontal drilling because they provide progressive contact and open helical flow paths.

Final selection depends on the BHA model and formation.

Which blade style is suitable for vertical wells?

Straight and spiral blades can both be used.

Straight blades are frequently selected where direct stabilization and large axial flow channels are preferred.

Are non-magnetic stabilizers available?

Yes.

Non-magnetic Integral Blade Stabilizers are available for use near MWD, LWD and directional survey tools.

What hardfacing options are available?

Options include tungsten-carbide inserts, crushed-carbide hardfacing, carbide blocks and casing-friendly wear overlays.

Can the stabilizer be redressed?

Yes.

Worn blade surfaces can be redressed when the body and blade base remain within the approved repair limits.

Are custom connections available?

Yes.

NC, REG and customer-specified connection arrangements can be manufactured according to the approved tool design.

Can the stabilizer be supplied Box × Box?

Yes.

Box × Box, Box × Pin and Pin × Box arrangements are available.

Can the stabilizer include a Float Valve bore?

Yes.

A float bore and retainer arrangement can be included where required.

Is the product manufactured to API Spec 7-1?

Integral Blade Stabilizers can be manufactured and inspected according to applicable API Spec 7-1 requirements when included in the purchase specification.

Does API Spec 7-2 apply to the complete stabilizer?

No.

API Spec 7-2 applies to qualifying rotary-shouldered connections and their gauging requirements.

Does the stabilizer prevent differential sticking?

It can reduce broad Drill Collar contact with the wellbore, but it cannot eliminate differential-sticking risk.

Pressure overbalance, filter cake, formation permeability, stationary time and hole cleaning must also be controlled.

How is the correct stabilizer selected?

Selection requires:

• Hole size
• Required blade OD
• Body OD
• Internal bore
• Near-Bit or String position
• Straight or spiral blades
• Three or four blades
• Top and bottom connections
• Formation and abrasiveness
• Hardfacing requirement
• Alloy or non-magnetic material

Information Required for Quotation

Please provide:

• Nominal hole size
• Bit diameter
• Required stabilizer blade OD
• Full-gauge or under-gauge configuration
• Near-Bit or String Stabilizer
• BHA position
• Straight or spiral blades
• Open or high-wrap spiral
• Three or four blades
• Top connection
• Bottom connection
• Box or Pin orientation
• Required body OD
• Required internal bore
• Fishing-neck OD and length
• Required overall length
• Blade crown length
• Leading taper angle
• Trailing taper angle
• Formation type
• Formation compressive strength
• Formation abrasiveness
• Maximum rotary speed
• Maximum operating torque
• Maximum tensile load
• Maximum dogleg severity
• Well inclination
• Vertical, directional or horizontal application
• Drilling-fluid type
• Mud density
• Solids content
• Chloride concentration
• Maximum flow rate
• Maximum operating temperature
• Alloy-steel or non-magnetic material
• H₂S concentration
• CO₂ concentration
• Sour-service requirement
• Hardfacing type
• Casing-friendly wear-surface requirement
• Float-valve bore requirement
• Stress-relief groove requirement
• Boreback requirement
• NDE requirements
• Third-party inspection
• Documentation requirements
• Required quantity
• Destination country
• Delivery schedule

Request a Technical Quotation

Goldenman supplies Integral Blade Stabilizers for Near-Bit and String BHA applications in vertical, directional, horizontal and extended-reach wells.

The published product range includes:

• 3-3/4–36 in working ODs
• Spiral and straight blade configurations
• Three- and four-blade designs
• Near-Bit and String Stabilizers
• Full-gauge and under-gauge options
• AISI 4145H Modified alloy-steel bodies
• Non-magnetic material configurations
• Tungsten-carbide and casing-friendly wear surfaces
• NC and API Regular connections
• Box × Box, Box × Pin and Pin × Box arrangements
• Float-valve bores
• Stress-relief grooves and borebacks
• Stabilizer redressing services

Complete tools can be supplied with material traceability, mechanical-property reports, UT and MPI records, thread-gauge reports, blade-OD inspection, hardfacing records and final dimensional documentation.

Email: info@goldenman.com