Downhole & Surface Tools for Oil and Gas Well Construction
Drilling a well requires far more than a rig, drill pipe, and a bit. The drill string is a highly engineered assembly of specialized tools, each performing a specific function: maintaining trajectory, absorbing vibration, providing weight, isolating formations, recovering from stuck pipe, and protecting the integrity of the wellbore and surface equipment.
Hoger Sanat Pars supplies a comprehensive range of drilling tools manufactured to API, DS-1, and NS-1 standards from qualified global manufacturers. Every tool is supplied with full material certification, dimensional inspection, NDE records, and traceability documentation.
Drill Bits
Drilling Tools Categories at a Glance
| Category | Primary Function | Governing Standard |
|---|---|---|
| Drill Bits | Formation cutting and penetration | IADC codes, API 7-1 (connections) |
| Drill Pipe | Torque transmission and fluid circulation | API 5DP, DS-1 |
| Heavy Weight Drill Pipe | Transitional stiffness and weight | API 7-1, DS-1 |
| Drill Collars | Weight on bit and directional control | API 7-1, NS-1 |
| Stabilizers | BHA centralization and trajectory control | API 7-1, DS-1 |
| Reamers & Hole Openers | Wellbore enlargement and conditioning | API 7-1 |
| Downhole Motors (PDM / Mud Motors) | Downhole power for directional drilling | API 7-2 |
| Jars & Accelerators | Stuck pipe freeing through impact force | API 7-1, DS-1 |
| Shock Subs & Vibration Dampeners | Absorb destructive drilling vibrations | API 7-1 |
| Crossovers & Adapter Subs | Connect dissimilar thread types and sizes | API 7-1, DS-1 |
| Fishing Tools | Recovery of stuck or lost equipment from the wellbore | API 7-1, proprietary designs |
| Drilling Accessories | Lifting, handling, and auxiliary BHA components | API 8C, API 7-1 |
1. DRILL BITS
Formation Cutting & Penetration Tools
The drill bit is the cutting tool at the very bottom of the drill string. It is the component that physically breaks, shears, or crushes the formation rock to create the wellbore. Bit selection is the single most impactful decision affecting rate of penetration (ROP), wellbore quality, directional control, and overall drilling cost per foot.
Drill Bit Types
| Type | Cutting Mechanism | Best For |
|---|---|---|
| Fixed Cutter (PDC) | Polycrystalline diamond cutters shear the rock. No moving parts | Soft to medium-hard formations. Long runs. Dominant in modern drilling |
| Roller Cone (TCI / Milled Tooth) | Rotating cones with tungsten carbide inserts or steel teeth crush and gouge the formation | Medium to hard formations. Interbedded lithologies. Versatile |
| Hybrid | Combination of PDC blades and roller cones | Transitional formations. Interbedded hard/soft layers. High torque stability |
| Impregnated Diamond | Diamond grit embedded in matrix material. Grinds the formation | Ultra-hard, abrasive formations. Geothermal, basement drilling |
| Coring Bits | Hollow center cuts a cylindrical core sample | Formation evaluation. Geological analysis |
PDC Bit Classification (IADC Fixed Cutter Code)
The IADC code uses four characters to describe bit type:
| Position | Meaning | Example Values |
|---|---|---|
| 1st Character | Body material | M (Matrix), S (Steel), D (Diamond/Impregnated) |
| 2nd Character | Cutter density | 1 (Very Light) through 9 (Very Heavy) |
| 3rd Character | Cutter size | 1 (>24mm) through 4 (8mm), 5-9 for diamond |
| 4th Character | Bit profile | 1 (Flat) through 9 (Very Long) |
Example: M423 = Matrix body, moderate cutter density, 13mm cutters, medium profile
Roller Cone Bit Classification (IADC Roller Cone Code)
| Position | Meaning | Values |
|---|---|---|
| 1st Character | Cutting structure & formation hardness | 1 (Soft) through 8 (Extremely Hard) |
| 2nd Character | Formation hardness sub-class | 1 through 4 |
| 3rd Character | Bearing type & gauge protection | 1 (Standard Open) through 7 (Sealed Journal with Gauge) |
| 4th Character | Additional features | A (Air), C (Center Jet), etc. |
Example: 537 = Hard formation TCI, sealed journal bearing, with gauge protection
Bit Selection Factors
| Factor | Consideration |
|---|---|
| Formation Hardness & Abrasiveness | Determines cutter type (PDC vs. TCI) and diamond grade |
| Formation Homogeneity | Interbedded formations may require hybrid or impregnated bits |
| Directional Requirements | PDC bits with specific blade count and gauge design for steerability |
| Motor vs. Rotary Drive | Motor RPM affects cutter cooling. Roller cones have RPM limits |
| Hole Size | Determines available bit diameter range |
| Drilling Fluid Type | Oil-based mud cools PDC cutters better than water-based |
| Bit Hydraulics | Nozzle configuration for cuttings removal and cutter cooling |
2. DRILL PIPE
Covered in full detail under OCTG section. Drill pipe is an OCTG product used in drilling operations.
3. HEAVY WEIGHT DRILL PIPE (HWDP)
Covered in full detail under OCTG section.
4. DRILL COLLARS
Covered in full detail under OCTG section.
5. STABILIZERS
BHA Centralization & Trajectory Control
Stabilizers are cylindrical tools with protruding blades or ribs installed at strategic positions in the bottomhole assembly. They centralize the BHA within the wellbore and control the side force and tilt angle at the bit, thereby managing wellbore inclination (build, drop, or hold angle). A well-designed stabilizer placement program is the foundation of directional drilling.
Stabilizer Types
| Type | Description | Application |
|---|---|---|
| Integral Blade Stabilizer (IBS) | Blades machined directly from a single alloy steel forging. No welded or bolted parts | Highest strength. Premium BHA applications. High dogleg environments |
| Sleeve Stabilizer | Interchangeable wear sleeve with blades mounted on a mandrel. Sleeve replaceable when worn | Cost-effective. Abrasive formations where blade wear is high |
| Welded Blade Stabilizer | Blades welded onto a central body | Lower cost. Non-critical applications. Limited fatigue life |
| Non-Magnetic Stabilizer | Manufactured from austenitic stainless steel (P550, P650) | Near MWD tools to prevent magnetic interference with directional sensors |
| Near-Bit Stabilizer | Placed immediately above the bit | Maximum directional control. Controls bit tilt for build, drop, or hold |
| String Stabilizer | Placed higher in the BHA | Controls BHA stiffness and pendulum effect |
Stabilizer Blade Configurations
| Configuration | Description | Application |
|---|---|---|
| Straight Blade | Blades parallel to tool axis | Standard. Vertical and low-angle wells |
| Spiral Blade | Helical blade profile. 360° wall contact | Reduces differential sticking. Preferred for deviated wells |
| 3-Blade | Three equally spaced blades | Smaller hole sizes. General use |
| 4-Blade | Four equally spaced blades | Larger hole sizes. Better centralization |
| 6-Blade | Six blades | Maximum wall contact. Large diameter, high angle |
Stabilizer Specifications
| Parameter | Range |
|---|---|
| Tool OD | Typically 1/16″ to 1/8″ under bit size for straight blade. 1/32″ for spiral |
| Blade Length | 8″ to 24″ depending on tool size and design |
| Material | AISI 4145H Modified (standard), Austenitic SS (non-magnetic) |
| Hardfacing | Tungsten carbide hardbanding on blade faces for wear resistance |
| Connections | API NC, API REG, API FH per BHA requirements |
| Standards | API 7-1, DS-1, NS-1 |
Stabilizer Placement Strategy
| Well Trajectory | Placement | Effect |
|---|---|---|
| Vertical | Near-bit + string stabilizer high in BHA | Pendulum effect holds hole vertical |
| Build Angle | Near-bit stabilizer only | Bit tilted up. Builds angle |
| Hold Angle | Near-bit + mid-BHA stabilizer | Stabilized assembly holds tangent |
| Drop Angle | No near-bit stabilizer. String stabilizer high | Pendulum drops angle |
6. REAMERS & HOLE OPENERS
Wellbore Enlargement & Conditioning Tools
Reamers and hole openers enlarge a pilot hole to the final wellbore diameter or condition the wellbore wall to full gauge. They are essential when drilling through swelling formations, salt sections, or when the bit produces an undergauge hole. They are also used for under-reaming—enlarging the hole below a casing shoe where the casing ID restricts the bit size.
Reamer Types
| Type | Description | Application |
|---|---|---|
| Fixed Hole Opener | PDC or TCI cutters mounted on a solid body. Constant OD | Enlarging pilot hole. Run above the bit. Reliable and simple |
| Hydraulic Hole Opener | Cutters extend when hydraulic pressure is applied. Retract when pressure drops | Under-reaming below casing. Allows tripping through restricted ID |
| Near-Bit Reamer | Placed directly behind the bit | Simultaneously drills pilot hole and reams to final diameter |
| String Reamer | Placed higher in the BHA | Maintains gauge through abrasive or swelling formations |
| Underreamer | Expandable cutters for enlargement below casing | Drilling out from under casing shoe. Deepwater. Side tracking |
| Roller Reamer | Multiple roller elements provide gauge contact | Reduces torque and drag. Conditions wellbore wall |
Reamer Specifications
| Parameter | Range |
|---|---|
| Pilot Hole Size | Matches bit diameter |
| Final Hole Size | Up to 2-3 times pilot diameter (depending on tool design) |
| Cutter Type | PDC, TCI, or combination |
| Activation | Fixed (no mechanism), Hydraulic (pressure-actuated), Mechanical (set-down weight or rotation activated) |
| Material | 4145H Modified, non-magnetic options |
| Standards | API 7-1 |
7. DOWNHOLE MOTORS (PDM / MUD MOTORS)
Downhole Power for Directional Drilling
A positive displacement motor (PDM), commonly called a mud motor, converts hydraulic energy from the drilling fluid into mechanical rotation at the bit. This enables directional drilling (in combination with a bent housing or bent sub) and provides additional RPM at the bit independent of drill string rotation—critical for PDC bit performance and for sliding operations in directional wells.
Mud Motor Components
| Component | Function |
|---|---|
| Power Section | Rotor (chrome-plated or coated steel helix) inside stator (elastomer-lined housing). Fluid pumped through progressive cavities forces rotor to turn |
| Transmission Section | Universal joint or flexible shaft that converts eccentric rotor motion to concentric rotation at the drive shaft |
| Bearing Section | Thrust and radial bearings support the drive shaft and transmit WOB to the bit |
| Drive Shaft | Rotates the bit. Houses the bit box connection |
| Bent Housing | Adjustable or fixed angle bend that enables directional control. Typically 0° to 3° |
| Dump Valve | Allows fluid to drain from the drill string during tripping to prevent wet connections |
| Stabilizer Sleeve | Integral or add-on stabilizer for motor centralization |
Motor Configurations
| Configuration | Description | Application |
|---|---|---|
| Straight Motor | No bend. Direct drive | Vertical drilling. Increasing bit RPM |
| Fixed Bend Motor | Single fixed bend angle. Typically 1.5°, 1.83°, 2.12°, 2.38° | Directional drilling. Build, drop, or turn |
| Adjustable Bend Motor | Bend angle adjustable on surface (typically 0° to 3° in increments) | Versatile. Can be reconfigured for different well sections without changing motor |
| Short Radius Motor | Articulated design for high doglegs (>20°/100 ft) | Short radius horizontal wells |
| High-Temperature Motor | Stator elastomer rated for elevated temperature (>150°C). Metal-to-metal power section option for extreme heat | Geothermal, HPHT |
Motor Specifications
| Parameter | Typical Range |
|---|---|
| OD | 2-7/8″ to 11-1/4″ |
| Lobe Configuration | 1:2, 3:4, 4:5, 5:6, 7:8 (rotor:stator lobes). More lobes = higher torque, lower speed |
| Flow Rate | 80 – 4,000 GPM depending on size |
| Bit Speed | 80 – 250 RPM at rated flow |
| Torque | 500 – 50,000+ ft-lbs depending on size and configuration |
| Operating Temperature | Standard: 120°C. HT: 150-175°C. Extreme: 200°C+ |
| Lost Circulation Material (LCM) Tolerance | Standard stators tolerate limited LCM. Special designs available for high LCM drilling fluids |
Motor Selection Factors
| Factor | Consideration |
|---|---|
| Hole Size | Determines motor OD (typically 1″ to 1.5″ smaller than bit size) |
| Required Bit RPM | PDC bits need higher RPM. Roller cone bits have lower RPM limits |
| Torque Requirement | Hard formations, large bits, high WOB require higher torque motors |
| Bend Angle | Determines build rate capability |
| Temperature | Stator elastomer must withstand BHST plus frictional heating |
| Drilling Fluid Compatibility | Oil-based mud, water-based mud, foam, air—stator elastomer must be compatible |
| LCM Content | High LCM fluids may plug motor. Special rotors available |
8. DRILLING JARS & ACCELERATORS
Stuck Pipe Recovery Through Controlled Impact
Drilling jars are mechanical or hydraulic tools installed in the BHA that deliver a high-energy axial impact to free stuck pipe. When the drill string becomes stuck—due to differential sticking, mechanical sticking, or cuttings packing—the jar is activated by applying tension (for upward jarring) or set-down weight (for downward jarring). The stored elastic energy in the drill string above the jar is released as a high-velocity impact at the stuck point.
An accelerator (or intensifier) is a companion tool run above the jar. It contains a compressible medium (silicone fluid or mechanical spring) that amplifies the impact force by accelerating the mass above the jar at the moment of release.
Jar Types
| Type | Actuation | Description |
|---|---|---|
| Hydraulic Jar | Hydraulic metering | Fluid is forced through a restricted orifice when tension or compression is applied. After a controlled time delay (30-90 seconds), a valve opens and the jar fires |
| Mechanical Jar | Mechanical latch | Pre-set tripping mechanism releases at a predetermined load. No time delay. Fires instantly on reaching set load |
| Hydro-Mechanical Jar | Combined hydraulic + mechanical | Hydraulic time delay for control. Mechanical release for reliability |
| Double-Acting Jar | Both directions | Capable of jarring upward (fishing) and downward (breaking stuck point) |
Jar Specifications
| Parameter | Typical Range |
|---|---|
| OD | 3-1/8″ to 11″ |
| Jar Stroke | 6″ to 12″ |
| Maximum Overpull | 200,000 to 1,000,000+ lbs depending on size |
| Operating Temperature | Standard: 120°C. HT: 200°C+ |
| Material | AISI 4340/4145, Inconel components for sour service |
| Standards | API 7-1, DS-1 |
Jar Placement in the BHA
Jars should be positioned to maximize impact at the stuck point while minimizing fatigue on the jar and its connections. Typically placed in the transition zone between HWDP and drill collars, with the accelerator directly above.
9. SHOCK SUBS & VIBRATION DAMPENERS
Absorbing Destructive Drilling Vibrations
Shock subs are mechanical dampening devices installed in the BHA to absorb axial and torsional vibrations generated by the bit and by drill string dynamics. Uncontrolled vibration causes premature bit failure, MWD/LWD tool damage, drill string fatigue, and reduced ROP. Shock subs isolate the sensitive BHA components and drill string from these destructive forces.
Shock Sub Types
| Type | Dampening Mechanism | Application |
|---|---|---|
| Hydraulic Shock Sub | Fluid-filled chamber with metering piston. Dissipates energy as heat | General BHA vibration control. Most common |
| Mechanical (Spring) Shock Sub | Belleville washer stack or coil spring. Absorbs and returns energy | Axial vibration. Cost-effective |
| Torsional Shock Sub | Absorbs rotational vibration. Protects connections and motors | Stick-slip mitigation. Highly deviated wells |
| Combined Axial-Torsional | Absorbs both vibration modes | Comprehensive protection |
Placement
- Behind the bit or motor (directly absorbs bit vibration)
- Below MWD/LWD tools (protects sensitive electronics)
- Above heavy BHA components (isolates drill string from BHA vibration)
10. CROSSOVERS & ADAPTER SUBS
Covered in full detail under OCTG Accessories section.
11. FISHING TOOLS
Recovery of Stuck or Lost Equipment from the Wellbore
Fishing is the operation of retrieving equipment that has become stuck, lost, or broken off in the wellbore. This can be anything from a few joints of drill pipe to an entire BHA, a logging tool, or a piece of junk that fell into the well. Fishing tools are specialized devices designed to engage, grip, cut, mill, or jar the stuck equipment free.
Fishing Tool Categories
| Category | Tools | Function |
|---|---|---|
| External Catch | Overshot, Die Collar, Taper Tap | Grip the outside of the fish |
| Internal Catch | Spear (Casing Spear, Tubing Spear, Oversize Spear) | Grip the inside of the fish |
| Junk Removal | Junk Basket, Boot Basket, Junk Mill, Magnet | Remove small debris from the hole bottom |
| Milling & Cutting | Section Mill, Washover Shoe, Chemical Cutter, Jet Cutter | Cut pipe or mill away obstructions |
| Jarring & Impact | Fishing Jar, Bumper Sub, Intensifier | Deliver impact to free stuck fish |
| Engagement & Indication | Lead Impression Block, Free Point Indicator | Identify the top and condition of the fish |
Common Fishing Tools
| Tool | Description |
|---|---|
| Overshot | External catch tool. Slips or grapple grip the OD of the fish. Can apply tension, torsion, and circulation |
| Spear | Internal catch tool. Slips expand inside the fish ID |
| Die Collar | Hardened internal threads grip the OD. Screwed onto the fish OD. Lower strength than overshot |
| Taper Tap | Tapered, hardened threads screw into the fish ID |
| Junk Basket | Annular coring bit with catcher. Retrieves small, irregular debris |
| Reverse Circulation Junk Basket | Fluid circulated down annulus, up through tool. Lifts debris into basket |
| Magnet | Retrieves ferrous metal pieces from hole bottom |
| Mill | Tungsten carbide or diamond cutting faces to grind up metal obstructions |
| Washover Shoe | Cuts and washes over stuck pipe. Frees differential sticking |
| Section Mill | Cuts a window in casing for sidetracking or abandonment |
| Lead Impression Block | Soft lead surface lowered onto fish. Impression reveals fish top condition and position |
| Free Point Indicator | Determines the depth at which pipe is stuck. Stretch measurements and strain gauge readings |
Fishing Job Planning
Successful fishing requires careful analysis before any tool is run:
- Identify the Fish: Exactly what is stuck? OD, ID, connection type, material, length
- Determine Stuck Point: Free point indicator or stretch calculations
- Understand Stuck Mechanism: Differential sticking, mechanical sticking, cuttings packing, key seating?
- Select Fishing Tool: Based on fish geometry and stuck mechanism
- Estimate Required Overpull: Maximum safe pull without parting the string
- Plan Jarring Strategy: Where to place jars for maximum impact at the stuck point
- Have Contingency Ready: If primary fishing attempt fails, what is next? Washover, cut and retrieve, sidetrack?
12. DRILLING ACCESSORIES
Handling, Protection & Auxiliary Equipment
| Equipment | Function | Standard |
|---|---|---|
| Lift Subs | Provide lift shoulder for elevators | API 8C |
| Lift Plugs | Threaded plugs for lifting pipe joints | API 5CT |
| Elevators (Casing / Tubing / Drill Pipe) | Latch around pipe body for hoisting | API 8C |
| Slips (Manual & Pneumatic) | Grip pipe in rotary table to suspend string | API 7K |
| Tongs (Manual & Hydraulic) | Apply makeup torque to connections | API 7K |
| Stabbing Guides | Align pin into box during makeup | Client specification |
| Drift Mandrels | Verify minimum ID of every joint before running | API 5CT |
| Thread Compound | API-modified thread compound for API connections. OEM-specified for premium | API RP 5A3 |
| Hardbanding Wire | Tungsten carbide welding wire for tool joint and stabilizer wear protection | Proprietary |
| Non-Magnetic Drill Collar Covers | Protect NMDC from wear and magnetic contamination | Client specification |
Drilling Tools Inspection & Documentation
All drilling tools are subject to rigorous inspection throughout their service life per DS-1 and NS-1 standards:
| Inspection Category | Coverage | Frequency |
|---|---|---|
| Category 3 | Visual and dimensional. Critical areas only | Between wells |
| Category 4 | Category 3 + full-length ultrasonic testing (UT) for wall thickness and internal defects | Every 2-3 wells or as specified |
| Category 5 | Category 4 + Magnetic Particle Inspection (MPI) of all critical areas + full connection inspection | Every major operation or after overload event |
Downhole & Surface Tools for Oil and Gas Drilling Operations
HSP supplies a comprehensive range of drilling tools and equipment for vertical, directional, and horizontal well construction. From the bit to the top drive, we source API-spec and DS-1 compliant tools from qualified global manufacturers.
Our drilling tools portfolio covers the complete Bottom Hole Assembly (BHA) , wellbore conditioning, and drilling string components required by drilling contractors, E&P operators, and service companies.
·
- )
- Drill pCollars
Thick-walled, heavy tubulars placed directly above the bit. Provide the primary source of Weight on Bit (WOB) and contribute to directional control.
· Slick Drill Collars: Smooth outer diameter, cost-effective for vertical wells.
· Spiral Drill Collars: Machined spiral grooves reduce differential sticking risk by minimizing wall contact area.
· Non-Magnetic Drill Collars (NMDC): Manufactured from high-quality austenitic stainless steel (P550, P650). Used near the Measurement-While-Drilling (MWD) tool to prevent magnetic interference with directional sensors.
Standard: API 7-1, NS-1.
- Stabilizers
Stabilizers centralize the BHA within the wellbore and control bit tilt and side force to manage inclination (build, drop, or hold angle).
· Integral Blade Stabilizers (IBS): Blades machined directly into a single steel forge. High strength, premium option.
· Sleeve Stabilizers: Replaceable wear sleeves on a mandrel body. Cost-effective for abrasive formations.
· Non-Magnetic Stabilizers: For use near MWD tools.
· Near-Bit Stabilizers: Placed immediately behind the bit for maximum directional control.
- Reamers & Hole Openers
Used to enlarge a pilot hole to the final wellbore diameter or to condition the wellbore to gauge (smooth the wall, remove ledges and doglegs).
· Fixed Hole Openers: PDC or TCI cutters on a fixed body.
· Hydraulic / Expandable Hole Openers: Cutters extend by hydraulic pressure; retract for tripping, enabling under-reaming below casing.
· String Reamers: Placed within the BHA to maintain gauge through abrasive formations.
· Near-Bit Reamers: Placed directly behind the bit.
- Downhole Motors & Turbines
Provide power directly at the bit for directional and performance drilling.
· Positive Displacement Motors (PDM / Mud Motors): Use drilling fluid flow to rotate the bit via a Moineau-type power section (rotor and stator). Essential for directional, horizontal, and extended-reach drilling.
· Configurations: Straight motor, bent housing motor (adjustable or fixed angle), short-radius motor.
· Power Section: High-speed (low torque) or high-torque (low speed) configurations depending on bit type and formation.
· Turbodrills: Fluid-driven turbine motors for high-RPM drilling in hard, abrasive formations (historically common in Russian and Middle Eastern applications).
- Jars & Shock Tools
Deployed within the BHA to manage downhole dynamics and recover from stuck pipe events.
· Drilling Jars: Deliver a high-impact axial blow to free stuck pipe. Available as:
· Hydraulic Jars: Controlled firing mechanism, field-adjustable. Most common in modern drilling.
· Mechanical Jars: Pre-set at surface, robust design.
· Double-Acting Jars: Capable of jarring both upward (freeing) and downward (breaking).
· Shock Subs: Absorb axial and torsional vibration from the bit, protecting MWD/LWD tools, motors, and surface equipment from damaging vibration harmonics.
- Crossovers, Subs & Accessories
Short, specialized connections used to adapt, protect, and enhance BHA components.
Item Function
Bit Sub / Bit Adapter Connects the bit to the motor or drill collar when thread types differ
Lift Sub / Elevator Sub Provides a lift shoulder for handling tools during tripping
Saver Sub A sacrificial sub that protects the bottom connection of a motor or MWD tool from wear during repeated bit changes
Float Sub Houses a float valve to prevent backflow of cuttings and formation fluids into the drill string
Circulating Sub Allows diversion of flow to clean the wellbore or spot pills without tripping
Junk Sub / Boot Basket Catches metallic debris from milling or drilling operations to prevent bit and motor damage
Crossover Sub Connects two different thread types/sizes within the BHA
Pony Collar A short drill collar used for precise BHA length adjustment
Quality Standards & Inspection
We source drilling tools manufactured to the following industry standards:
Standard Scope
API 7-1 Rotary drill stem elements (drill collars, subs, stabilizers)
API 7-2 Threading and gauging of rotary shouldered connections
API 5DP Drill pipe specification
DS-1 (TH Hill) Drill stem design and inspection standard (widely adopted globally)
NS-1 Drill stem manufacturing and inspection standard
API 8C / 8B Drilling and production hoisting equipment (if covering top drives, elevators)
All tools are supplied with full material certifications, dimensional inspection reports, and NDE (MPI/UT) records as required.
Our Drilling Tools Sourcing Capability
We Source We Do Not Currently Source
Drill Bits (PDC, TCI, Diamond) Top Drives & Rotary Tables
Drill Pipe, HWDP, Drill Collars Drawworks & Hoisting Systems
Stabilizers, Reamers, Hole Openers Mud Pumps & High-Pressure Manifolds
Downhole Motors (PDM / Turbodrills) Solids Control Equipment (Shakers, Desanders)
Jars, Shock Subs, Crossovers Blowout Preventers (BOPs)
Lifting Subs, Float Subs, Accessories Casing Running Tools
Note: If you require surface drilling equipment (BOPs, top drives, iron roughnecks), we can engage our network on a project-specific basis. Please contact our technical team to discuss.
Talk to Our Drilling Tools Team
Whether you need a single PDC bit for a challenging interbedded section or a complete BHA package for a multi-well campaign, our technical sourcing team is ready to support your requirements.