Description

Drilling Mud Cleaner for Oilfield Solids Control, WBM, OBM & SBM

SGPE manufactures Drilling Mud Cleaner equipment for oilfield solids control, drilling fluid treatment and mud recovery on land and offshore drilling rigs.

SGPE combined configurations use desander hydrocyclones, desilter hydrocyclones and a linear-motion underflow shaker to remove sand and silt while returning reusable drilling fluid to the active mud system.

Typical processing capacity ranges from approximately 500 to 1500 GPM (120–360 m³/h). Common project arrangements use 10-inch desander hydrocyclones, 4-inch desilter hydrocyclones and a three- or four-panel recovery shaker.

The equipment handles water-based mud (WBM), weighted WBM, oil-based mud (OBM), synthetic-based mud (SBM), high-density drilling mud and conventional unweighted fluids.

Oilfield buyers also use terms such as Oilfield Mud Cleaner, Mud Conditioner, Hydrocyclone Mud Cleaner, Drilling Fluid Cleaner, Desander Desilter Mud Cleaner and 3-in-1 Mud Cleaner. The terminology varies between drilling contractors and equipment manufacturers, but the core purpose remains the same: remove intermediate drilled solids and recover useful drilling fluid from hydrocyclone underflow.

In a conventional solids-control train, the mud cleaner normally operates after the primary shale shaker and before the drilling mud decanter centrifuge. This position allows the system to remove intermediate solids before repeated circulation breaks them into finer low-gravity particles.

Typical applications include land rigs, offshore platforms, jack-up rigs, semi-submersibles, drillships, surface and intermediate hole sections, directional and horizontal wells, extended-reach drilling, high-ROP programs, deep wells and surface drilling-fluid treatment for HPHT well programs.

SGPE supplies standalone units, mud-tank-mounted packages, offshore configurations, replacement equipment and complete drilling fluid treatment systems for drilling contractors, rig operators, EPC companies, oilfield service companies and equipment distributors.

Email:  info@sgpe.com
Tel/Whatsapp:  +86 186-1599-5239

Description

After the primary shale shaker removes larger drill cuttings, smaller sand and silt particles remain suspended in the circulating drilling fluid.

If these solids stay in the system, mud pumps, drill pipe and the bit continue to reduce their particle size. As the solids become finer, low-gravity solids concentration can rise, making mud rheology harder to control and increasing dilution demand.

The mud cleaner removes much of this intermediate solids fraction before it becomes more difficult to separate.

A centrifugal sand pump sends drilling fluid to the hydrocyclone manifold. The hydrocyclones concentrate denser solids into the underflow, while cleaner liquid exits through the overflow.

The underflow then falls onto the recovery shaker. Instead of discarding the complete concentrated stream, the shaker removes larger unwanted formation solids and allows reusable drilling fluid to return to circulation.

This process supports sand removal, silt removal, drilling fluid recovery, drilling mud recycling, LGS control, weighted mud treatment, barite retention, dilution reduction and drilling waste minimization.

Fluid recovery becomes especially important with weighted WBM, OBM and SBM because these drilling fluids contain valuable base liquid, weighting material and treatment chemicals.

Product Overview

Effective oilfield solids control relies on staged separation.

The primary shale shaker removes larger cuttings. The mud cleaner then targets intermediate sand and silt. A decanter centrifuge processes finer solids farther downstream.

Each machine therefore handles a different part of the drilled-solids load.

Inside the mud cleaner, hydrocyclones use centrifugal force to separate denser particles from the liquid phase. Cleaner drilling fluid exits through the overflow, while solids-rich underflow reaches the recovery shaker.

The shaker provides a second separation stage. Reusable liquid passes through the screen and returns to the active mud system, while rejected solids move toward the rig’s drilling waste equipment.

Process Function	Operating Value
Sand Removal	Reduces abrasive coarse formation solids
Silt Removal	Controls intermediate drilled solids
Drilling Fluid Recovery	Returns usable liquid to circulation
Drilling Mud Recycling	Reduces unnecessary whole-mud losses
Weighted Mud Treatment	Supports recovery of treated drilling fluid
Barite Retention	Helps reduce avoidable weighting-material losses
LGS Control	Removes drilled solids before further degradation
Dilution Reduction	Reduces dependence on excessive dilution
Equipment Protection	Limits abrasive solids reaching pumps and piping
Centrifuge Load Reduction	Removes intermediate solids before fine treatment
Waste Reduction	Reduces liquid carried into the drilling waste stream

This arrangement provides a compact treatment stage for new drilling rigs, equipment replacement projects and complete drilling fluid recycling systems.

Technical Specifications

Core Process & Hydraulic Data

Technical Parameter	Typical / Configurable Specification	Selection Basis
Product	Drilling Mud Cleaner	Oilfield solids control
Main Function	Sand and silt removal with drilling fluid recovery	Mud program
Treatment Stage	Secondary / tertiary solids control	Rig process layout
Processing Capacity	Approx. 120–360 m³/h	Maximum circulating rate
Flow Capacity	Approx. 528–1584 GPM	Mud-system flow
Separation Method	Hydrocyclones + recovery shaker	Solids-control program
Desander Cone Diameter	10 in. / approx. DN250	Sand removal
Desander Cone Quantity	1–3	Required flow
Desilter Cone Diameter	4 in. / approx. DN100	Silt removal
Desilter Cone Quantity	8–16	Required flow
Hydrocyclone Material	Wear-resistant polyurethane	Abrasive drilling solids
Typical Feed Pressure	Approx. 0.25–0.40 MPa	Hydrocyclone performance
Imperial Pressure Reference	Approx. 36–58 psi	Hydraulic reference
Typical Feed Connection	6 in. / DN150	Feed piping
Typical Overflow Connection	8 in. / DN200	Mud return
Underflow Routing	Recovery shaker	Drilling fluid recovery
Mud Type	Weighted / unweighted	Drilling program
Drilling Fluids	WBM / OBM / SBM	Application
Installation	Standalone / mud-tank mounted / integrated	Rig layout

Recovery Shaker & Screening Data

Shaker Parameter	Typical / Configurable Range	Selection Basis
Shaker Type	Underflow recovery shaker	Hydrocyclone discharge
Motion	Linear motion	Solids conveyance
Vibration Motors	Dual motors	Shaker platform
Typical Motor Power	Approx. 2 × 1.7–2.0 kW	Selected shaker
Typical Total Motor Power	Approx. 3.4–4.0 kW	Shaker configuration
Screen Quantity	Typically 3 or 4 panels	Capacity
Typical Screen Area	Approx. 2.0–2.7 m²	Selected platform
Screen Frame	Composite / steel	Project requirement
Screen Opening	Selected for mud and recovery target	Separation target
G-Force	Adjustable	Fluid handling
Typical Maximum G-Force	Up to approx. 7.5 G	Selected shaker
Deck Angle	Adjustable	Fluid pool and solids conveyance
Solids Discharge	Open shaker discharge	Waste-system interface

Final dimensions, screen area, motor ratings and interface details follow the approved SGPE technical datasheet and GA drawing.

500 GPM, 1000 GPM & 1500 GPM Mud Cleaner Configurations

Nominal flow provides the first reference point for Drilling Mud Cleaner sizing.

Capacity Class	Nominal Flow	Typical Desander Arrangement	Typical Desilter Arrangement	Typical Feed	Typical Overflow	Common Application
500 GPM Class	120 m³/h / 528 GPM	1 × 10 in.	8 × 4 in.	6 in.	8 in.	Compact land-rig systems
1000 GPM Class	240 m³/h / 1056 GPM	2 × 10 in.	12 × 4 in.	6 in.	8 in.	Standard drilling rigs
1500 GPM Class	360 m³/h / 1584 GPM	3 × 10 in.	16 × 4 in.	6 in.	8 in.	High-flow land and offshore systems

500 GPM Class

The 500 GPM configuration suits compact land-rig mud systems, lower circulation rates and installations with limited tank-top space.

A typical package combines one 10-inch desander cone, multiple 4-inch desilter cones and a compact recovery shaker.

1000 GPM Class

A 1000 GPM Mud Cleaner suits many conventional oil and gas drilling systems.

This capacity provides a practical balance between processing rate, hydrocyclone quantity and equipment footprint. It also fits many rig upgrade and replacement projects.

1500 GPM High-Capacity Class

The 1500 GPM Mud Cleaner supports higher circulation rates on large land rigs, high-ROP programs and offshore drilling systems.

A larger hydrocyclone bank handles the required flow, while the recovery shaker processes the corresponding underflow.

Nominal GPM alone does not define the correct machine. Mud density, viscosity, solids loading, available pump head, screen selection and installation layout also influence final sizing.

Hydrocyclone Separation & Mud Cleaner Particle Size

Hydrocyclones provide the main centrifugal separation stage.

Treatment Stage	Typical Size / Range	Main Function
Primary Shale Shaker	Screen-dependent	Removes larger drilled cuttings
Desander Hydrocyclone	10 in.; commonly used around 40–100 μm	Sand-size solids removal
Desilter Hydrocyclone	4 in.; commonly used around 20–74 μm	Finer silt removal
Fine Small-Cone Systems	Can extend toward the mid-teen micron range under suitable conditions	Finer solids treatment
Recovery Shaker	Screen-dependent	Classifies hydrocyclone underflow
Decanter Centrifuge	Fine / ultrafine solids	Downstream fine-solids control

These ranges are practical oilfield references rather than guaranteed absolute cut points.

Actual hydrocyclone performance changes with drilling fluid density, viscosity, feed pressure, flow rate, solids concentration, cone geometry and apex wear.

For this reason, searches for Mud Cleaner particle size, hydrocyclone cut point, desander micron size or desilter separation range should not be reduced to one fixed number.

SGPE reviews the complete drilling fluid condition and circulation requirement when selecting the hydrocyclone package.

Desander & Desilter Hydrocyclone Stages

The 10-inch desander hydrocyclones remove coarser abrasive solids that remain after primary shaker treatment.

These particles can accelerate wear when they repeatedly circulate through mud pumps, valves, piping and the drill string.

Depending on required flow, a combined unit can use one, two or three desander cones. Polyurethane construction provides abrasion resistance, while individual cone isolation allows operators to adjust active capacity as circulation changes.

The 4-inch desilter cones target smaller silt-size particles. Typical configurations use 8, 12 or 16 cones in parallel.

Smaller hydrocyclones depend heavily on correct hydraulic loading. Adding more cones does not improve separation when the feed pump cannot maintain sufficient flow and pressure.

The desander bank, desilter bank, centrifugal pump, manifold and piping therefore need to operate as one hydraulic system.

For weighted mud service, the active hydrocyclone arrangement and underflow-screen strategy should be selected around fluid-recovery and barite-retention objectives rather than simply running every cone stage at maximum capacity.

How a Drilling Mud Cleaner Works

A centrifugal sand pump draws drilling fluid from the selected mud tank compartment and delivers it to the hydrocyclone manifold.

The fluid enters the hydrocyclones tangentially. Centrifugal force moves denser particles toward the cone wall, while cleaner liquid migrates toward the center and leaves through the overflow.

Solids-rich underflow exits through the hydrocyclone apex and falls onto the recovery shaker.

The shaker retains larger unwanted formation solids while reusable drilling fluid passes through the screen.

Recovered fluid returns to the active mud system. Rejected solids move toward the drilling waste handling equipment.

In SGPE combined configurations, this provides a compact desander + desilter + recovery shaker treatment process within one solids-control package.

Mud Cleaner Feed Pressure & Centrifugal Pump Sizing

Stable hydrocyclone feed pressure is essential for consistent separation.

Typical mud cleaner systems operate around 0.25–0.40 MPa (36–58 psi) at the hydrocyclone manifold.

Low pressure reduces centrifugal separation efficiency. Excessive pressure can accelerate cone wear and disturb underflow behavior.

The Mud Cleaner feed pump must therefore provide sufficient flow and head after accounting for drilling fluid properties and piping losses.

Pump Selection Data	Why It Matters
Maximum Circulating Rate	Defines required pump flow
Required Manifold Pressure	Defines pump head
Mud Density	Influences hydraulic loading
Mud Viscosity	Influences pump and hydrocyclone performance
Suction Pipe Size	Affects pump inlet condition
Discharge Pipe Size	Affects velocity and pressure loss
Pipe Length	Adds friction loss
Elbows and Valves	Add pressure loss
Elevation Difference	Adds static head
Active Cone Quantity	Changes distribution-flow requirement

SGPE can supply the centrifugal sand pump for Mud Cleaner service together with the unit.

When an existing rig pump remains in service, its flow, head, motor rating and connection information allow hydraulic compatibility to be reviewed before final equipment selection.

Weighted Mud Cleaner, Fluid Recovery & Barite Retention

Weighted drilling fluid is one of the applications where underflow recovery becomes especially important.

Hydrocyclones separate solids according to their behavior in the rotating flow. They do not identify barite and drilled solids as different materials.

As a result, hydrocyclone underflow can contain both undesirable formation solids and useful weighting material.

The recovery shaker provides another classification stage. Larger unwanted solids remain above the screen, while reusable liquid and suitably sized fine material pass through and return toward the active system.

This process helps reduce whole-mud loss, base-fluid consumption and unnecessary weighting-material discard.

The objective is not to recover every fine particle. The solids-control program must balance drilled-solids removal, drilling fluid recovery and barite retention.

For this reason, Weighted Mud Cleaner, Barite Recovery Mud Cleaner and Mud Cleaner for Weighted Drilling Fluid searches should be understood as a combined hydrocyclone-and-screen selection problem rather than a simple hydrocyclone sizing exercise.

Low-Gravity Solids Removal & Mud Conditioning

Low-gravity solids mainly originate from drilled formation material.

If they remain in circulation, they can increase plastic viscosity, affect gel properties and raise dilution requirements.

Repeated passage through pumps and the bit also reduces particle size, making the solids progressively harder to remove.

The mud cleaner removes a significant portion of intermediate solids before this degradation occurs.

A high-speed decanter centrifuge can then handle finer solids downstream.

Together, these stages support LGS removal, drilling fluid conditioning, solids concentration control and more stable mud properties.

WBM, OBM, SBM & High-Density Drilling Mud

The unit can be configured for the main drilling fluid systems used in oil and gas wells.

Drilling Fluid	Main Treatment Priority	Mud Cleaner Value
Unweighted WBM	Sand and silt removal	Controls solids accumulation
Weighted WBM	Solids removal with fluid recovery	Supports barite and mud retention
OBM	High-value liquid recovery	Reduces base-oil loss
SBM	Fluid recovery and solids control	Supports offshore mud management
High-Density Mud	Control drilled solids without excessive dilution	Supports mud-weight and rheology management

Water-Based Mud

A Water-Based Mud Cleaner removes sand and silt that remain after primary shaker treatment.

This becomes especially important during surface and intermediate hole sections, where high circulation rates and heavy solids loading can challenge the active mud system.

Weighted Water-Based Mud

Weighted WBM requires a balance between solids removal and useful mud retention.

The recovery shaker helps reject undesirable drilled material while returning reusable liquid and suitably sized fine material to the active system.

Oil-Based Mud

An Oil-Based Mud Cleaner places greater emphasis on drilling fluid recovery because base oil, emulsifiers, wetting agents and treatment chemicals carry significant replacement value.

Directional, horizontal, deep and extended-reach wells often make this recovery function particularly important.

Synthetic-Based Mud

A Synthetic-Based Mud Cleaner commonly serves offshore drilling programs where both fluid recovery and solids control matter.

Jack-up rigs, semi-submersibles and drillships also introduce requirements for compact equipment layout, corrosion protection and suitable electrical systems.

High-Density Drilling Mud

High-density drilling fluid carries a significant concentration of weighting material.

Mud weight, viscosity, feed pressure, solids loading and screen selection therefore need to be evaluated together rather than treated as separate variables.

Oil & Gas Drilling Applications

Application	Configuration Focus	Main Selection Priority
Onshore Oil Drilling	500–1500 GPM land-rig package	Flow and tank layout
Onshore Gas Drilling	Standard / high-capacity package	Solids loading
Surface-Hole Sections	High-throughput treatment	High solids volume
Intermediate-Hole Sections	Desander/desilter treatment	Sand and silt control
Directional Drilling	WBM / OBM configuration	Mud rheology
Horizontal / ERD Wells	High-solids-load configuration	Cuttings loading
High-ROP Drilling	High-capacity treatment	Solids throughput
Deep-Well Drilling	Weighted WBM / OBM / SBM	Mud recovery
High-Density Mud	Recovery-focused package	Barite retention
HPHT Well Programs	Surface drilling-fluid treatment	Mud-property control
Offshore Platforms	Compact offshore package	Footprint and corrosion
Jack-Up Rigs	Tank-integrated package	Deck space
Semi-Submersibles	Offshore solids-control package	Reliability
Drillships	High-capacity offshore package	High-value fluid recovery
Deepwater Drilling	OBM / SBM treatment	Fluid recovery
Rig Upgrade	Replacement package	Existing interfaces
Brownfield Project	Custom retrofit package	Dimensional compatibility

High-ROP, Directional, Horizontal & Deep-Well Drilling

High-ROP drilling creates more drilled solids per hour and increases the load on every downstream treatment stage.

If mud-cleaning capacity falls behind the drilling rate, sand and silt accumulate in the active system and place additional load on the centrifuge.

Directional, horizontal and extended-reach wells add another challenge because stable mud rheology plays an important role in hole cleaning, cuttings transport and wellbore stability.

For these wells, a mud cleaner removes intermediate formation solids before they degrade further and helps recover valuable WBM, OBM or SBM from hydrocyclone underflow.

Deep wells often use weighted drilling fluids, increasing the value of fluid and barite retention.

For HPHT well programs, the mud cleaner remains a surface solids-control machine. It treats the engineered drilling fluid used during the well program but does not experience bottomhole HPHT pressure or temperature.

Land Rig Mud Cleaner

A Land Rig Mud Cleaner prioritizes processing capacity, straightforward maintenance and simple mud-tank integration.

SGPE configures land-rig units around common 500, 1000 and 1500 GPM circulation requirements.

The equipment can mount directly on a mud tank or on a dedicated skid. Feed and overflow positions follow the rig piping arrangement, while solids discharge can align with a cuttings trough, screw conveyor or drilling waste system.

For mobile rigs, transport dimensions, lifting arrangement and available tank-top space also influence the layout.

Offshore & Deepwater Mud Cleaner

SGPE supplies Offshore Mud Cleaner configurations for fixed platforms, jack-up rigs, semi-submersibles and drillships.

Offshore projects place greater emphasis on compact footprint, maintenance access, marine corrosion protection and electrical requirements.

The integrated hydrocyclone-and-recovery-shaker arrangement reduces the number of separate solids-control skids around the mud system.

Deepwater drilling frequently uses high-value OBM or SBM, increasing the economic value of fluid recovery.

Offshore Project Data	Design Consideration
Maximum Circulating Rate	Hydrocyclone and shaker capacity
Mud Type	WBM / OBM / SBM configuration
Maximum Mud Weight	Hydraulic loading
Deck Footprint	Skid dimensions
Installation Height	Hydrocyclone layout
Feed Location	Piping arrangement
Overflow Location	Mud return arrangement
Solids Discharge	Waste-system interface
Voltage / Frequency	Electrical configuration
Area Classification	Motor and control selection
Coating Specification	Marine corrosion protection
Service Clearance	Screen and hydrocyclone maintenance
Lifting Requirement	Offshore installation

Mud Tank Mounted Mud Cleaner & Solids-Control Integration

A Mud Tank Mounted Mud Cleaner integrates the hydrocyclone bank and recovery shaker directly with the drilling fluid tank system.

This arrangement shortens flow paths and reduces field alignment work.

The package can include the mud cleaner, centrifugal feed pump, tank piping and recovered-fluid collection section.

For new drilling rigs, equipment elevation, tank layout, piping routes and service clearance can be coordinated before fabrication.

For retrofit projects, the same engineering approach helps fit a new unit to an existing tank with minimal field modification.

The mud cleaner can also form part of a complete Drilling Fluid Recycling System.

Equipment	Main Role
Drilling Shale Shaker	Primary cuttings removal
Mud Gas Separator	Handles gas-cut returns where required
Vacuum Degasser	Removes entrained gas
Mud Desander	Dedicated sand removal
Mud Desilter	Dedicated silt removal
Drilling Mud Cleaner	Hydrocyclone treatment with fluid recovery
Drilling Mud Decanter Centrifuge	Fine-solids treatment
Mud Tank	Fluid storage and circulation
Centrifugal Pump	Fluid transfer and hydrocyclone feed
Mud Agitator	Maintains solids suspension
Mud Gun	Supports tank circulation
Mud Mixing Hopper	Mixes drilling fluid materials

SGPE supplies the cleaner individually or as part of a complete Oilfield Solids Control Equipment package.

Matching capacities across the system helps prevent one treatment stage from becoming a bottleneck.

Mud Cleaner vs. Shale Shaker, Desander, Desilter & Centrifuge

Each piece of solids-control equipment performs a different duty.

Equipment	Separation Method	Main Solids Target	Recovery Screen	Typical Role
Shale Shaker	Vibrating screens	Larger drill cuttings	Integral	Primary solids control
Mud Desander	Large hydrocyclones	Sand-size solids	Normally no	Secondary treatment
Mud Desilter	Small hydrocyclones	Silt-size solids	Normally no	Tertiary treatment
Mud Cleaner	Hydrocyclones + recovery shaker	Sand / silt / concentrated underflow	Yes	Intermediate solids control with fluid recovery
Decanter Centrifuge	High-speed centrifugal separation	Fine / ultrafine solids	No	Fine-solids and density management

A standalone desander or desilter suits systems that only require hydrocyclone separation.

A mud cleaner adds a recovery screen beneath the hydrocyclone underflow and therefore reduces avoidable drilling fluid loss.

This difference becomes especially important in weighted drilling fluid systems.

A decanter centrifuge operates at a finer separation level and complements the mud cleaner rather than replacing it.

Mud Cleaner Screen Mesh & Shaker Screen Selection

The recovery screen controls the balance between solids rejection and drilling fluid recovery.

A finer opening increases solids rejection but can reduce fluid-handling capacity when mud viscosity or solids loading rises.

A more open screen handles more liquid but can return more fine material to circulation.

Weighted mud requires additional care because excessive screen fineness can increase weighting-material losses.

OBM and SBM further increase the economic value of recovered liquid.

For this reason, Mud Cleaner screen mesh, Mud Cleaner shaker screen selection and weighted mud screen size should be selected around fluid type, density, viscosity, solids loading, hydrocyclone underflow and the required recovery target.

The finest available screen is not automatically the best operating choice.

Main Components

Component	Main Function	Selection / Maintenance Focus
Desander Hydrocyclones	Remove coarse sand	Cone quantity and wear
Desilter Hydrocyclones	Remove finer silt	Cone quantity and pressure
Hydrocyclone Manifold	Distributes drilling fluid	Hydraulic balance
Pressure Gauge	Monitors feed pressure	Operating condition
Cone Isolation Arrangement	Adjusts active capacity	Circulation changes
Underflow Recovery Shaker	Recovers drilling fluid	Shaker capacity
Shaker Screens	Separate solids from reusable fluid	Screen selection
Vibration Motors	Generate linear motion	Motor condition
Screen Deck	Supports screening and solids conveyance	Deck angle
Fluid Collection Section	Collects recovered drilling fluid	Cleanliness
Structural Skid	Supports complete assembly	Rig interface
Feed Connection	Receives pumped mud	Size and position
Overflow Connection	Returns treated fluid	Size and position
Solids Discharge	Transfers rejected solids	Waste-system interface
Electrical Controls	Operate shaker equipment	Power and area requirements

Materials, Electrical System & Installation Data

Drilling fluid carries abrasive formation solids, so wear resistance directly affects service life.

SGPE uses wear-resistant polyurethane hydrocyclones for standard configurations. Replaceable apex components simplify maintenance in high-wear areas.

Internal cone wear gradually changes hydrocyclone geometry and can reduce separation performance before an external leak appears.

The fabricated steel skid supports the hydrocyclone bank and continuous shaker vibration. The layout also maintains access around screens, vibration motors and the manifold.

Land-rig units use industrial anti-corrosion coating systems. Offshore projects can specify marine surface-protection requirements.

The recovery shaker normally uses two synchronized vibration motors. Voltage and 50 Hz or 60 Hz frequency can be matched to the drilling rig power supply.

For classified locations, the motor and control package follows the specified hazardous-area requirements.

There is no universal footprint for every 500, 1000 or 1500 GPM unit. Final dimensions and operating weight follow the approved project GA drawing.

Interface Data	Why It Matters
Overall Length / Width	Confirms available footprint
Overall Height	Confirms vertical clearance
Feed Connection	Matches pump piping
Overflow Connection	Matches mud return
Connection Positions	Reduces field modifications
Shaker Deck Elevation	Controls recovered-fluid return
Solids Discharge Direction	Matches waste handling
Screen Removal Clearance	Allows routine maintenance
Hydrocyclone Clearance	Allows cone replacement
Motor Access	Supports service work
Operating Weight	Defines structural support

Replacement Mud Cleaner, Retrofit & Custom Manufacturing

SGPE manufactures Replacement Drilling Mud Cleaners for existing land and offshore drilling rigs.

A successful replacement needs to match more than the original GPM rating because mud tanks, feed pumps, piping, electrical systems and waste equipment often remain unchanged.

Existing Equipment Data	Replacement Design Use
Original GA Drawing	Defines equipment envelope
Existing Nameplate	Confirms original rating
Processing Capacity	Confirms hydraulic requirement
Overall Dimensions	Confirms physical fit
Feed / Overflow Connections	Matches existing piping
Connection Positions	Reduces field modifications
Skid Elevation	Maintains fluid routing
Solids Discharge Direction	Matches waste system
Existing Pump Data	Checks hydraulic compatibility
Existing Screen Type	Supports spare standardization
Voltage / Frequency	Matches rig power
Area Classification	Defines electrical configuration
Site Photographs	Confirms actual installation

When the original GA drawing is unavailable, verified field measurements, equipment nameplate data and clear site photographs provide the basis for replacement engineering.

Custom projects can modify capacity, hydrocyclone quantity, shaker platform, screen arrangement, feed and overflow connections, piping direction, skid dimensions, coating, electrical configuration and mud-tank integration.

This supports Mud Cleaner retrofit, rig upgrade, brownfield solids-control modification, offshore MRO and replacement solids-control equipment projects.

Spare Parts & Maintenance Support

Reliable operation depends on routine inspection and access to wear parts.

SGPE supplies replacement hydrocyclones, apex components, shaker screens, screen seals, pressure gauges, vibration-motor parts, clamps, fasteners and electrical service components with new equipment or as operating spares.

Maintenance Item	Main Check
Hydrocyclone Body	Internal wear and erosion
Apex	Wear or plugging
Manifold	Leakage and connection condition
Pressure Gauge	Accurate feed-pressure indication
Shaker Screens	Tears and sealing
Screen Deck	Solids buildup
Vibration Motors	Fasteners, noise and operation
Structural Bolts	Tightness
Fluid Collection Area	Solids accumulation
Electrical Connections	Secure installation

A damaged screen can return unwanted solids to the active mud system, while worn hydrocyclones can lose separation efficiency long before complete failure.

Routine inspection therefore protects both drilling fluid quality and equipment service life.

SGPE Manufacturing, Engineering & Quality Control

SGPE operates a petroleum equipment manufacturing base in Yancheng, Jiangsu Province, China.

The company’s published profile covers approximately 20,000 m² of factory area and about 10,000 m² of building area, with more than 100 employees, 25+ professional technical personnel and over 100 sets of processing equipment.

For a mud cleaner project, engineering starts with the drilling fluid system rather than only the requested equipment name.

Capacity, mud type, density, viscosity, feed pressure, active cone quantity, screen arrangement, pump duty, tank dimensions and site interfaces all affect the final configuration.

This helps avoid a common procurement problem: selecting a nominally correct 1000 or 1500 GPM machine that does not match the installed feed pump, piping or mud tank.

SGPE coordinates fabrication, assembly, inspection, documentation and export preparation. The company’s petroleum equipment has been supplied to customers in more than 50 countries and regions.

Inspection & Project Documentation

Equipment configuration and critical interfaces are checked before shipment.

Inspection / Document	Main Purpose
Approved GA Drawing	Confirms dimensions and interfaces
Technical Datasheet	Records final configuration
Dimensional Inspection	Confirms equipment dimensions
Hydrocyclone Manifold Inspection	Checks cone arrangement
Piping Leakage Check	Confirms piping integrity
Shaker Functional Test	Confirms mechanical operation
Vibration Motor Check	Confirms correct operation
Electrical Inspection	Checks wiring and controls
Coating Inspection	Checks surface protection
Operating Manual	Supports commissioning and operation
Maintenance Manual	Supports routine servicing
Spare Parts List	Supports maintenance planning
Packing List	Supports export shipment

Customer inspection requirements and third-party witness points can be incorporated into the agreed project scope.

Drilling Mud Cleaner Manufacturer, Supplier & Factory-Direct Support

Buyers comparing a Drilling Mud Cleaner Manufacturer, Oilfield Mud Cleaner Supplier, Mud Cleaner Factory or Solids Control Equipment Supplier usually need more than a catalogue flow rating.

The selected equipment must match the drilling fluid properties, maximum circulation rate, feed-pump duty, recovery-shaker capacity and available installation space.

SGPE connects the quotation with equipment configuration, GA drawing review, manufacturing, inspection and project documentation.

This factory-direct approach is particularly useful for custom mud cleaners, replacement mud cleaners, offshore packages, mud-tank-mounted equipment and complete solids-control systems.

SGPE supports individual equipment purchases, multi-unit drilling rig packages, EPC procurement, MRO projects and distributor requirements.

Buyers can begin with a complete technical datasheet or simply provide the maximum flow rate, drilling fluid type and available installation space.

Drilling Mud Cleaner Price & Quotation Factors

Buyers searching for Drilling Mud Cleaner price, Drilling Mud Cleaner for sale, Oilfield Mud Cleaner cost, 1000 GPM Mud Cleaner price, 1500 GPM Mud Cleaner quotation or Offshore Mud Cleaner supplier often begin with nominal capacity.

However, final cost depends on the complete project scope.

Price Factor	Effect on Quotation
Processing Capacity	Changes hydrocyclone and shaker package
Desander / Desilter Quantity	Changes cone and manifold scope
Recovery Shaker	Changes mechanical configuration
Screen Quantity / Type	Changes equipment and spares
Vibration Motors	Changes electrical configuration
Feed / Overflow Connections	Changes fabrication
Skid Dimensions	Changes structural scope
Centrifugal Feed Pump	Adds hydraulic equipment
Mud Tank Integration	Adds tank and piping scope
Offshore Configuration	Adds marine-project requirements
Coating Specification	Changes surface protection
Hazardous-Area Electrical Package	Changes electrical scope
Custom Layout	Adds engineering
Replacement Matching	Adds interface review
Third-Party Inspection	Adds inspection coordination
Documentation	Changes project dossier
Spare Parts	Changes supply scope
Quantity	Influences production planning

For an accurate quotation, provide actual operating and installation data rather than requesting a generic price based only on GPM.

Why Choose SGPE?

SGPE treats the mud cleaner as part of the complete drilling fluid circulation and solids-control process rather than as an isolated hydrocyclone skid.

Technical selection considers maximum circulation rate, drilling fluid type, density, viscosity, expected solids loading, hydrocyclone pressure, feed-pump capacity, screen arrangement and rig layout.

SGPE supports land rigs, offshore drilling systems, weighted mud programs, OBM and SBM, high-ROP drilling, new-build equipment packages, rig upgrades and replacement projects.

Where a broader project scope is required, the mud cleaner can be coordinated with shale shakers, decanter centrifuges, mud tanks, centrifugal pumps, agitators and related drilling fluid equipment.

For international projects, SGPE combines manufacturing, application engineering, inspection, technical documentation and export supply through one technical and commercial contact.

RFQ Data Sheet

For a faster technical proposal and commercial quotation, provide the following information.

RFQ Item	Information Required
Product	Drilling Mud Cleaner
Quantity	Required quantity
Rig Type	Land rig / platform / jack-up / semi-sub / drillship
Application	Oil / gas drilling
Required Capacity	GPM / m³/h
Maximum Circulating Rate	GPM / m³/h
Drilling Fluid	WBM / OBM / SBM
Weighted Mud	Yes / No
Maximum Mud Weight	Required value
Mud Viscosity	Operating range
Expected Solids Loading	Available data
Hole Section	Surface / intermediate / deeper section
Expected ROP	Available data
Desander Requirement	Cone size / quantity
Desilter Requirement	Cone size / quantity
Screen Requirement	Existing or required specification
Feed Pressure	Available pressure
Feed Pump	Existing / SGPE supply
Feed Connection	Size and location
Overflow Connection	Size and location
Solids Discharge	Required direction
Available Length	Installation envelope
Available Width	Installation envelope
Available Height	Installation envelope
Mud Tank Drawing	Provide for integration or replacement
Voltage	Rig power
Frequency	50 / 60 Hz
Area Classification	Project requirement
Coating	Land / offshore specification
Inspection	Customer / TPI requirement
Documentation	Required documents
Spare Parts	Commissioning / operating spares
Existing GA Drawing	Replacement project
Existing Nameplate	Replacement project
Field Photographs	Replacement project
Destination	Country / project

If a complete datasheet is not ready, begin with maximum circulation rate, drilling fluid type, rig type and available installation space. These four items provide enough information for an initial equipment-selection review.

Frequently Asked Questions About Drilling Mud Cleaners

1. What is a Drilling Mud Cleaner and how does it work?

A Drilling Mud Cleaner is an oilfield solids-control unit that combines hydrocyclone separation with an underflow recovery shaker. Drilling fluid is pumped into the hydrocyclones, where centrifugal force concentrates denser sand and silt into the underflow while cleaner liquid exits through the overflow.

The concentrated underflow then falls onto a fine-screen recovery shaker. Larger unwanted formation solids are discharged, while reusable drilling fluid passes through the screen and returns to the active mud system.

Depending on the required treatment program, an Oilfield Mud Cleaner can use desander hydrocyclones, desilter hydrocyclones or a combined desander-desilter arrangement. This configuration is widely used on land rigs, offshore drilling units and drilling fluid recycling systems to improve solids removal while reducing unnecessary mud loss.

2. What is the difference between a Mud Cleaner, Shale Shaker, Desander and Desilter?

A Drilling Shale Shaker provides primary solids control by removing larger drill cuttings directly from the returning drilling fluid. A Mud Desander uses larger hydrocyclones to remove sand-size particles, while a Mud Desilter uses smaller hydrocyclones to target finer silt.

A Mud Cleaner adds a recovery shaker beneath the hydrocyclone underflow. This additional screening stage allows reusable drilling fluid to be recovered instead of discarding the complete concentrated stream.

The difference becomes particularly important when processing weighted WBM, OBM or SBM, where whole-mud loss can carry significant cost. In a complete solids-control system, the shale shaker, mud cleaner and decanter centrifuge normally work as complementary treatment stages rather than competing alternatives.

3. How do I choose a 500 GPM, 1000 GPM or 1500 GPM Mud Cleaner?

The first selection factor is the maximum expected drilling fluid circulation rate. A 500 GPM Mud Cleaner corresponds to approximately 120 m³/h, a 1000 GPM Mud Cleaner to around 240 m³/h, and a 1500 GPM Mud Cleaner to approximately 360 m³/h.

Capacity alone, however, is not enough to select the correct equipment. Mud density, viscosity, solids concentration, expected ROP, hole section, hydrocyclone feed pressure, feed-pump capacity and available installation space all affect the final configuration.

Compact 500 GPM units can suit smaller land rigs, while 1000 GPM systems are common for conventional drilling operations. Higher-capacity 1500 GPM packages are better suited to large land rigs, high-ROP drilling programs and offshore solids-control systems with higher circulation demands.

4. What hydrocyclone sizes are commonly used on a Drilling Mud Cleaner?

SGPE combined Drilling Mud Cleaner configurations commonly use 10-inch desander hydrocyclones for coarser sand removal and 4-inch desilter hydrocyclones for finer silt treatment.

Typical arrangements can range from one to three 10-inch desander cones and approximately eight to sixteen 4-inch desilter cones, depending on the required flow rate and system configuration.

For example, a smaller 500 GPM package may use fewer active cones, while a 1000 or 1500 GPM system requires a larger hydrocyclone bank to handle the higher circulation rate.

The correct cone quantity must always match the available feed-pump flow and hydrocyclone operating pressure. Installing additional hydrocyclones without sufficient hydraulic capacity does not automatically improve separation performance.

5. What particle size can a Mud Cleaner remove?

The actual Mud Cleaner particle size or hydrocyclone cut point depends on drilling fluid properties and operating conditions rather than one fixed micron value.

As a practical oilfield reference, 10-inch desander hydrocyclones are commonly used for coarser solids around 40–100 μm, while 4-inch desilter hydrocyclones commonly operate in a finer range around 20–74 μm. Smaller-cone systems can extend toward the mid-teen micron range under suitable conditions.

Actual separation changes with mud density, viscosity, feed pressure, flow rate, solids concentration, hydrocyclone geometry and cone wear.

For this reason, desander micron size and desilter separation range should be treated as operating references rather than guaranteed absolute cut points. SGPE selects the hydrocyclone arrangement according to the actual drilling fluid and circulation requirements.

6. What feed pressure and centrifugal pump does a Mud Cleaner require?

A Mud Cleaner feed pump must provide stable flow and pressure so the hydrocyclones can generate sufficient centrifugal force for solids separation.

Typical hydrocyclone packages operate around 0.25–0.40 MPa, or approximately 36–58 psi, at the feed manifold. Low pressure can reduce separation efficiency, while excessive pressure can accelerate hydrocyclone wear and disturb the underflow pattern.

The centrifugal sand pump should be selected according to maximum flow rate, mud density, viscosity, suction and discharge pipe sizes, piping length, fittings and elevation difference.

For land-rig, offshore or replacement projects where an existing pump will remain in service, SGPE can review the pump flow, head, motor power and connection data to confirm whether it is suitable for the selected mud cleaner configuration.

7. Can a Mud Cleaner process weighted drilling mud and reduce barite loss?

Yes. Weighted Mud Cleaner applications are particularly important because the hydrocyclone underflow can contain both unwanted drilled solids and valuable weighting material.

Hydrocyclones separate particles according to their physical behavior in the rotating fluid. They do not chemically distinguish barite from formation solids. The recovery shaker therefore provides an important second separation stage.

Larger unwanted solids remain above the shaker screen, while reusable drilling fluid and suitably sized fine material can pass through and return to the active mud system.

The objective is not to recover every fine particle, but to balance drilled-solids removal, drilling fluid recovery and barite retention. Proper hydrocyclone operation and shaker screen selection can help reduce avoidable whole-mud and weighting-material losses in weighted WBM and other high-density drilling fluids.

8. Can a Drilling Mud Cleaner process WBM, OBM and SBM?

Yes. SGPE configures Drilling Mud Cleaner systems for water-based mud (WBM), weighted WBM, oil-based mud (OBM), synthetic-based mud (SBM) and high-density drilling fluids.

WBM applications mainly focus on sand, silt and low-gravity solids control. Weighted WBM requires additional attention to drilling fluid recovery and barite retention.

An Oil-Based Mud Cleaner places greater emphasis on liquid recovery because base oil, emulsifiers, wetting agents and treatment chemicals carry significant replacement value. SBM systems have similar recovery requirements and are frequently used in offshore drilling.

Typical applications include land rigs, directional and horizontal wells, deep wells, high-ROP drilling, offshore platforms, jack-up rigs, semi-submersibles and drillships. Final configuration should match mud properties, flow rate and project installation conditions.

9. What screen mesh should be used on a Mud Cleaner recovery shaker?

There is no single Mud Cleaner screen mesh that is suitable for every drilling fluid or drilling program.

A finer screen opening improves solids rejection, but it can reduce liquid-handling capacity when mud viscosity or solids loading is high. A more open screen allows more drilling fluid to pass through, but it may also return a larger amount of fine material to circulation.

Weighted drilling mud requires additional care because an excessively fine screen can increase unnecessary weighting-material losses.

The correct Mud Cleaner shaker screen selection should therefore consider mud type, density, viscosity, solids loading, hydrocyclone underflow rate and the required balance between solids rejection and drilling fluid recovery.

The finest available screen is not automatically the best operating choice, particularly in weighted WBM, OBM and SBM service.

10. Where is a Mud Cleaner installed in an oilfield solids-control system?

A Drilling Mud Cleaner normally operates downstream of the primary shale shaker and upstream of the fine-solids treatment stage, such as a drilling mud decanter centrifuge.

This position allows the shale shaker to remove larger drill cuttings first, while the mud cleaner handles intermediate sand and silt before these solids break down into finer low-gravity particles.

The equipment can be installed directly on a mud tank or supplied on a separate skid. Correct installation should provide stable pump suction, proper hydrocyclone feed pressure, suitable overflow routing, recovered-fluid return and an unobstructed solids-discharge path.

Mud-tank-mounted units are common on land rigs, while compact integrated configurations are often preferred on offshore platforms, jack-up rigs, semi-submersibles and drillships where deck space and piping layout are more restricted.

11. Does SGPE supply replacement, retrofit and custom Mud Cleaners?

Yes. SGPE supplies Replacement Drilling Mud Cleaner, retrofit and custom solids-control equipment for existing land and offshore drilling systems.

A replacement project needs to match more than the original GPM rating. Existing mud-tank dimensions, feed and overflow connections, skid elevation, solids-discharge direction, feed-pump capacity, electrical supply and maintenance clearance can all affect compatibility.

An existing GA drawing provides the best engineering reference. When the original drawing is unavailable, SGPE can work from verified dimensions, equipment nameplate information, pump data and clear site photographs.

Custom configurations can also modify hydrocyclone quantity, shaker platform, screen arrangement, piping direction, skid dimensions, coating and electrical requirements. This supports rig upgrades, brownfield projects, offshore MRO and solids-control system modernization.

12. What affects Drilling Mud Cleaner price and what information is required for a quotation?

The final Drilling Mud Cleaner price depends on processing capacity and the complete technical supply scope rather than nominal GPM alone.

A 500, 1000 or 1500 GPM configuration can differ in hydrocyclone quantity, recovery-shaker size, screen arrangement, vibration motors, piping connections, skid dimensions and feed-pump requirements. Offshore coating, hazardous-area electrical equipment, mud-tank integration, third-party inspection, spare parts and project documentation can also affect cost.

For an accurate Drilling Mud Cleaner quotation, provide the maximum circulation rate, drilling fluid type, mud weight, viscosity, rig type, available installation space, feed pressure, piping connections and electrical requirements.

For replacement projects, the existing GA drawing, nameplate, pump information and site photographs are also useful. SGPE will review the operating conditions and recommend the appropriate configuration before providing the corresponding technical proposal and quotation.

Request a Drilling Mud Cleaner Quote from SGPE

SGPE supplies 500–1500 GPM Drilling Mud Cleaner systems for land and offshore drilling, including standalone, mud-tank-mounted, weighted-mud, offshore and replacement configurations for WBM, OBM, SBM and high-density drilling fluids.

For new equipment, please provide the required flow rate, drilling fluid properties, rig type, installation space, piping connections and electrical requirements.

For replacement projects, send the existing GA drawing or nameplate together with key dimensions, feed and overflow connections, pump data and site photographs.

Based on your operating conditions and installation requirements, SGPE will select the suitable hydrocyclone, recovery shaker and feed-pump configuration and provide the corresponding technical proposal and quotation.

Email:  info@sgpe.com
Tel/Whatsapp:  +86 186-1599-5239