OUR PRODUCTS INCLUDE

New - SAGA Casing Packer (SCP)  
New - Lancaster High Performance Chokes  
Casing Accessories  
Collar  
Float Equipment & Accessories  
Reamer Shoes  
Float and Plug Sets for Tubing-less (Monobore) Completion  
Liner Hanger Systems  
MAP OIL TOOLS For Supplying Completion Equipment  

 

SAGA CASING PACKER (SCP)

SAGA CASING PACKERContinuous Mandrel SCP assemblies are designed with packer elements in 4 Foot (1.22m) and 10 Foot (3.05m). SAGA Casing Packer elements soundly conform to irregular or washed-out hole diameters. Steel reinforcement slats are used within the elements to ensure that the SCP self-centers itself in vertical, deviated, or horizontal wellbores.
Tools are available in Standard and Special clearance models. Standard clearance tools are used where higher differential pressures are encountered across the packer element. Special clearance tools are used for applications where restricted hole diameters may occur. Continuous Mandrel SCP assemblies are typically inflated with cement displacement fluid. An integral screen prevents coarse particles from entering the valve system. The valves are designed with high quality materials, which will not erode when abrasive materials are pumped through the system. SCP valve system provides positive closing, after the element has been fully inflated to pre-determined pressure. After the shear valve has shifted to the final closed position, a mechanical locking device ensures that no further movement will occur.

SCP inflatable elements are available with Standard and Advanced elastomer compounds. Standard elastomer compounds may be used for temperatures up to 240° F (115°C). Advanced elastomer compounds are made available for applications in which temperatures reach up to 350° F (180° C).

SAGA CASING PACKERSAGA CASING PACKERSAGA CASING PACKER

FEATURES
– The continuous one-piece mandrel eliminates the need for internal threaded connections.
– Reliable valve system which can be run above or below the inflation element
– Fully reinforced stainless steel slat’s end to end, standard seal length 4 ft and 10 ft
– Adjustable shear pressures
– Elastomer suitable for both normal and sour service
– Integral mandrel
– Can be inflated with any well fluid

BENEFIT
– Constructed using one piece casing mandrel
– No hidden internal connection
– No welding to the casing during construction
– Valve’s 3 way system consist of: opening valve, check valve and closing valve which maintain better casing string integrity.
– Large expansion ratio
– Multiple packer’s can be installed in a single casing string or liner
– Long element to run though highly deviated well

APPLICATION
– Stop gas annular migration
– Multi stage cementing
– Zona Isolation
– Scab liner
– One trip cement the radius horizontal completion
– Plug and abandonment
– Selective completion required for production test.

LANCASTER HIGH PERFORMANCE CHOKES

Production Chokes, Drilling Chokes, Retrofit Kits, Heater Chokes, Control Chokes, Actuators, Back-up Power Supplies

Lancaster Flow AutomationOGSI’s line of Lancaster production chokes offers unparalleled features and options. The operating torque is over 90% less than typical commodity style designs. Thus, the ease with which this equipment may be automated is without equal. With options like having no elastomers in direct contact with well bore fluids together with metallic bonnet seals, neither safety or performance has been compromised. A stainless steel micrometer style position indicator provides for precise readout of the orifice size. It remains on the choke even when mounting rotary type actuators.

With only 27 lb.-ft. of torque required for closing the stem against 15,000 psig downstream of the orifice, a small 17-pound (24 vDC) electric actuator (drawing 2.6 amps. at these conditions) is all that is required for automation. The unit may be operated using solar power and is easily removed while the choke is in service and under pressure. The choke is available in needle, cage, multi-stage cage, positive, and adjustable/ positive style trims. Regardless of the adjustable trim style, any type of actuator may be used with our standard components. Our choke and retrofit kits have been operating successfully offshore in the Gulf of Mexico since 1995.

When you are serious about your flow control, LFA provides genuine solutions.

  • No elastomeric seals (o-rings) are in contact with well bore fluids. Standard seal temperature range is -40ºF to 325ºF. Several styles of non-metallic and metallic bonnet seals are offered.
  • Our equipment requires extremely low operating torque (1.8 lb.-ft. per 1,000 psi downstream pressure). Automation has never been easier.
  • A single bonnet and trim configuration may be utilized for manual, linear pneumatic piston or diaphragm, linear hydraulic, or rotary electric actuation. Converting from needle type trim to cage type trim (and vice versa) only requires replacement of the stem, seat, and orifice indicator.
  • The large diameter orifice indicator is stainless steel and markings are accurate to the nearest .0001@. The entire surface of the orifice indicator is always visible and displays trim design details and open/close directions. An adjustable stainless steel pointer provides for easy reading of the choke orifice size.
  • Tungsten carbide trim is standard. Needle type (linear), multi-orifice cage type (linear and equal percent), and multi-orifice multi-stage type (linear) type trims are available with a single configuration bonnet and body. Positive and adjustable/positive trim types are also available. The full length of all carbide cages and seat liners are held in compression with a separate carrier.
  • Seat assemblies utilize a non-threaded design that cannot become loosened from flow induced vibration while in service which could lead to seat-to-body seal failures and body damage.
  • Our compact stainless operating lever, a mere 7.5@ long (190.5 mm), is easily removed when automating. The stem position locking feature is integral with the operating lever and is adjustable.
  • All bodies are forged and have a reinforced inlet nozzle area; large body reservoirs reduce internal erosion and extend trim life. A body cavity bleeder plug with the addition of a bonnet nut safety interlock is optional.
  • Our manufacturing processes do not include salt bath nitriding of wetted trim components (and their critical sealing surfaces). This results in improved corrosion resistance of the standard stainless steel trim components as well as superior seal performance.
  • The bearing housing is completely sealed and provided with a stainless steel lubrication fitting. Switch from manual to rotary actuation by simply removing the operating lever and mounting the small electric actuator. If a problem is ever encountered, the actuator may be safely removed and the operating lever reinstalled, all while the choke is throttling and under pressure.
  • Our lead screw is isolated from the environment to provide long life and consistently low operating torque. The special design and metallurgy utilized provide for an efficiency of almost 33%.
  • Retrofit bonnet kits and actuators are available for a number of commodity type choke styles and control valve assemblies. Installation of these kits is cost effective and usually easier than a routine trim change.
  • Modulating 24 vDC electric actuation is available and may be operated using solar power. 120/240 vAC units are also available. Our actuator is capable of making over 55 moves or Asteps@ per single revolution which equates to a stem adjustment of <0.003″ (.076 mm). The weight of our standard 24 vDC actuator is only 23 pounds (10.43 kg), which includes the mounting kit. The actuator is NEMA 4/7 and is suitable for Div. 1 hazardous locations, class I and II, Groups C, D, E, F, and G. Our small actuator will drive the choke stem even when the choke is pressure locked at P1 = P2 = 15,000 psig. The compact size of the overall package makes it ideal for use in FPSO turrets, on offshore platforms – especially unmanned platforms, or any other remote locations.

Lancaster production choke Unlike so many others, the Lancaster production choke is NOT just another copy, clone, or modification of a commodity choke line, it is the next generation of choke design. Each individual component has been designed to maximize unimaginable product interchangeability, metallurgy, performance, safety, and automation.

In a wellhead application, the choke should be the last valve to open and the first valve to close. No choke is easier to operate than this one. Whether you choose to automate or not, we recommend that you insist on installing a choke that operates easily, around the clock, at the working pressure stamped on the body. Install our user-friendly choke to save wear and tear on your gate valves and improve the overall safety of your well site operations.

Utilize our needle style trim to clean up or test your well prior to connecting the flow line. Then, if conditions dictate, install one of our cage trims to reduce noise and possible flashing or cavitation which may be encountered when producing water or condensate at high pressure drops along with the gas phase.

When desired, the actuator may be configured to fail in place, fail open, or fail closed. With the optional back-up power supply, the unit may be configured to fail closed on loss of power or command signal even in the event of a power failure. Weight of the 24 vDC actuator is a mere 23 pounds (10.43 kg) including the mounting kit.

Control Valves
Lancaster Flow Automation, LLC is also pleased to offer our new control valve technology. Featuring our cutting edge multi-stage designs, our valve offers you innovative solutions to your more challenging flow control applications. This new technology may even be retrofitted to our existing choke assemblies with ease.

Retrofit Kits
Lancaster Flow Automation leads the industry in versatility. Our unique design has allowed us to develop a series of “retro-fit” kits that give you, our customer, a greater amount of flexibility when it comes to controlling your wells.
We have the technology to adapt many versions of “conventional” (H2, JWA) chokes into actuated chokes. We are able to employ our low torque bonnet assemblies so that you can leave your existing choke body in line and only need to replace the top works. This will save you time and money and still allow you to upgrade the capability of your existing choke.

Actuators
Don’t be forced into using large stepping actuators to operate your choke. Using our chokes, you have the freedom to get away from unfriendly, expensive and bulky pneumatic diaphragm or stepping actuators. Our line of chokes can be operated at 15,000 psig with a small electrically powered (24vDC/110AC/220AC) actuator. When operating with 24vDC, our chokes can work onshore or offshore using only a small battery pack and solar array for power. This gives you unparalleled freedom and reliability when it comes to flow control in remote locations.

Drilling Chokes
Our line of high performance drilling chokes was designed with ease of operation and convenient service in mind. Our unique compact actuator means field service and trim replacements may be performed quickly and safely while minimizing down time. We offer our drilling chokes in 10,000, 15,000, and 20,000 psig working pressures and provide the necessary metallurgy on all of our wetted components for sour gas service. All drilling chokes have long life positive shut-off trim designs which utilize tungsten carbide (or better) trim components. Give us a call today and let us show you how we can improve your drilling, flow back, or well fracturing operations.

Precision 3D Modeling Lancaster Flow Automation has the personnel, products, equipment, tools, software, and imagination to take care of your flow control.

Download Lancaster Flow Automation Brochure here

CASING ACCESSORIES

STM Centralizers offer maximum stand-off to help prevent cement channeling and avoid differential sticking during running. We offer the most extensive and technical advanced portfolio of centralizers, stop collars, and other casing accessory tools. We constantly monitor the industry’s ever changing needs and apply our extensive engineering expertise to design unique equipment to meet the challenges of today and tomorrow.

We have been manufacturing Casing Accessories since 1984 and have manufactured and supplied over 2 million centralizers.

Welded and Non-Welded centralizers are manufactured from high-strength steel materials in all common casing/hole sizes combinations for reliability and durability. We also specialize in designing, manufacturing, testing and validating custom size centralizers to customer request.

Stop Collars preventing the movement of mechanical cementing products on the pipe and are manufactured to withstand high axial forces.

Slider Centralizers with 0 Lbs starting force are design for highly deviated and horizontal wells.

Along with equipment, STM’s experienced engineers can analyze the well profile and data and make detailed recommendations to assist you in selecting and installing the optimal equipment for your well design with the aid of our proprietary LATLOAD centralizer placement software.

Slider Centralizer Slip-on

Slider Centralizer Slip-onDesigned for highly deviated well and horizontal well application.
Has ZERO staring force, running force and high restoring force.
Bows are flexible to enable running through restrictions or under gauge well-bore sections.
Available in heavy-duty type or solid body SLIDER-3HD.

Centralizer–Bow Type

Centralizer–Bow TypeCentralizes casing string inside open hole (or casing) to increase effectiveness of cement. Provides.
Helps prevent differential sticking by holding casing away from side of well-bore.
Bows are flexible to enable running through restrictions or under gauge well-bore sections.
Available in latch on or hinged type.

Centralizer Flexi-Rigid

Centralizes casing string inside open hole (or casing) to increase effectiveness of cement.
Helps prevent differential sticking by holding casing away from side of well-bore.
Bows are flexible to enable running through restriction or under gauge well-bore sections.
Bows are more rigid compare to Bow Centralizer.

Rigid Centralizer–Welded Type

Centralizes casing string inside casing.
Available in latch on or hinged type.

Petal type Cement Basket

Acts as centralizer that also captures cement in integral basket which can improve primary cementing success in over gauge hole sections.
Also can be used when trying to capture cement to stop it form contaminating slotted screens etc.
Available in slip on only and supplied with integral stop collar.

Testing-Centralizers

A.P.I. test rig, can test all sizes of bow type centralizers to A.P.I. Spec 10D
Testing performed on a regular basis
All tests are fully documented

COLLAR

Stop Collar/Ring

Secures to assign to limit centralizer movement.
High holding force.

Heavy Duty Stop Collar

A beveled leading edge for minimizing any mechanical interference during running

Casing Scratcher & Cable Wall Cleaner

Removes or agitates wall-cake to enhance primary cementing conditions
Cable wall cleaner Similar to scratcher but less aggressive

Turbolator

Rigid centralizer for open hole application
Spiral vanes to generate turbulent flow of cement
Available in slip on only

Testing – Stop Collars

Stop collar test rig, can slippage test all sizes and types stop collars
Testing performed on a regular basis and at customer request
All tests are fully documented

FLOAT EQUIPMENT & ACCESSORIES

Float equipment is a critical component of the casing or liner string. It provides back pressure valves for well control and the shoe guides the casing to total depth. The float collar provides a landing point for casing wiper plugs, reinforces the lower end of the casing string, and ensures greater accuracy of cement slurry displacement.

STM offers field-proven technologies that are durable and resistant to wear, withstand long periods of circulation with highly abrasive fluids, and are rotary or PDC drillable. Our portfolio includes a complete line of precision-made float technologies including: Float Shoes, Float Collars, Guide Shoes and Reamer Shoes

We have been manufacturing Float Equipment since 1987 and have sold over 100,000 pieces
– We manufacture with CNC machines

Stab In Float Shoe

Back pressure valve, maintains well control by preventing fluids (or gas) with lower density than drilling fluids from entering casing
Back pressure valve prevents cement which has higher density than drilling fluids from back-flowing into casing after displacing
Integral recess to accommodate stab in drill-pipe stinger
And with addition of latch profile for drill-pipe wiper plug

Drill-pipe Dart for Stab in Latch in Stinger

Displaces cement inside drill-pipe.
Separates cement from displacement fluid inside

Stab In Stinger

Eliminates need to conventional top and bottom plugs.
Provides a seal between stab in float shoe and drill-pipe to enable cementing.
Large inside diameter allows passage of drill-pipe wiper plug.

Top and Bottom Plug Non Rotating

Bottom plug displaces mud and provides separation between mud and cement.
Top plug displaces cement and provides separation between cement and displacement fluid.
Plugs seat on top of float collar.
non rotating inserts to prevent plugs from spinning when drilling out.

Top and Bottom Plug

Bottom plug displaces mud and provides separation between mud and cement.
Top plug displaces cement and provides separation between cement and displacement fluid.
Plugs seat on top of float collar.

Float Collar Non Rotating

Back pressure valve, maintains well control by preventing fluids (or gas) with lower density than drilling fluids from entering casing.
Back pressure valve prevents cement which has higher density than drilling fluids from back-flowing into casing after displacing.
Provides seat for plugs once displacement is completed
integral non rotating profile top prevent plugs from spinning when drilling out with PDC or conventional bit.

Float Collar

Back pressure valve, maintains well control by preventing fluids (or gas) with lower density than drilling fluids from entering casing
Back pressure valve prevents cement which has higher density than drilling fluids from back-flowing into casing after displacing
Provides seat for plugs once displacement is completed

Float Shoe

Rounded nose to assist guiding casing to bottom.
Back pressure valve, maintains well control by preventing fluids (or gas) with lower density than drilling fluids from entering casing.
Back pressure valve prevents cement which has higher density than drilling fluids from backflowing into casing after displacing.

REAMER SHOES

SAGATRADE MURNI REAMER SHOE SYSTEM is a casing shoe that overcomes welbore obstructions to guide casing or liners to total depth (TD). The eccentric guide nose climbs ledges and negotiates obstructions while the cutting structure reams out tight spots or obstruction in the wellbore. Compatible with all casing and liner hanger assemblies, our Reamer Shoe provides highly effective protection against unexpected or anticipated casing and liner running problems. And has been specifically designed for potentially difficult wellbore conditions such as. swelling shale s, ledges and washed out areas of wellbore.

SAGATRADE MURNI REAMER SHOE Ensures that tubular reach desire depth first time, saving both time and costs.

PROVEN ECCENTRIC GUIDE NOSE HELPS IN TROUBLESOME FORMATIONS Equipped with a profiled nose that has the ability to freely orientate off obstructions and reams out tight spots or obstruction in the wellbore.

SURGE REDUCTION ENHANCEMENT Designed to minimize EDC and maximize By-pass Flow. Sagatrade Murni’s Reamer Shoe designed with smooth reaming surfaces, minimizes voids and fluid traps, thus maximizing surge reduction.

PENETRATES BY REAMING PAST OBSTRUCTIONS WITH OR WITHOUT ROTATION Due to the unique design of the tool, rotation is not necessary Eguipped with a reaming structure that re-establishes the hole size to the gauge of the tool, allowing easy passage of all casing, liner, and screen assemblies

INTEGRAL PLUNGER FLOAT VALVE Positive seal PDC drillable Double Plunger Valve, burst and collapse ratings meet and exceed casing ratings. The Phenolic material valve and Viton seal is designed to withstand high temperature, large volumes of fluids pumped at high flow rates. Suitable for both high and low pressure conditions.

CONNECTIONS Our Reamer Shoe connections are available in all types of Premium connections depending on reguests as well as with flusn connections.

ANTI AGGRESSIVE LEFT HAND BLADES MINIMIZE TORQUE Non aggressive reaming action with passive angled left-hand blades eliminites stalling and minimizes torque build up on thread connections.

SMOOTH BODY ELIMINATES SOLIDS BUILD UP The smooth body design has eliminated potential areas which can trap solids and cutting.

OPTIONAL INTEGRAL LOW TORQUE SLIDER-3HD CENTRALIZER Cw. BEVELED STOP COLLAR. Freely rotating SLIDER-3HD centralizer Installed above by 2 set of heavy duty beveled Stop Collar as per spacing programs as a bearing supports for the tool and reduces torque and drag during running operations.

CONNECTIONS

Our Reamer Shoe connections are available in all types of Premium connections depending on reguests as well as with flush connections.

RUN WITH INTEGRAL LOW TORQUE SLIDER-3HD CENTRALIZER Cw. BEVELED STOP COLLAR TO OPTIMIZE PERFORMANCE.

Freely rotating SLIDER-3HD centralizer installed above and below by 2 sets of heavy duty beveled Stop Collar as per spacing programs as a bearing supports for the tool and reduces torque and drag during running operations. The ultra low frictions SLIDER-3HD CENTRALIZER will minimize drag and maximize the rotational ability of Sagatrade Murni Reamer Shoe and tubular string that follows.

ANTI AGGRESSIVE LEFT HAND BLADES MINIMIZE TORQUE

Non aggressive reaming action with passive angled left-hand blades eliminates stalling and minimizes torque build up on thread connections.

INNOVATIVE SELF CLEANING CUTTING STRUCTURE

Superior innovative tapered cutting structure of Tungsten Carbide Composite Matrix Insert. Solids will not stick and there are no sharp extrusions to damage wellhead seals and tubular, Tungsten Carbide Composite Matrix Insert cutting is made in a special pattern, facilitating both rotating and reciprocating applications.

REAMER SHOE FLOAT VALVE

Reamer shoes are designed to incorporate the super Double Plunger Valve system, providing superior erosion resistance and backpressure holding capabilities that rated and exceed.

DYNAMICALLY POSITIONED CIRCULATING PORTS FOR EFFECTIVE HOLE CLEANING

Combination circulating port on the nose is utilized to maximize and maintain circulation. Recessed up-jet angled ports assist cuttings removal and hole cleaning and gives 360 degree cement placement.

EASY DRILL THRU CAPABILITY WITH PDC OR TRI-CONE BIT

The high strength profile alloy nose will anchor even in uncured cement to facilitate ease of drill out. The aluminum nose is easily drilled with both PDC and rock bits. The chip breaker holes in the nose assembly designed to create small aluminum chips to avoid “bird nesting” on the bit.

FLOAT AND PLUG SETS FOR TUBING-LESS (MONOBORE) COMPLETION

These 10,000psi rated Items were purpose designed, validated and manufactured for a major oil companies Tubing-less completion wells in the Mahakam Delta area of East Kalimantan, Indonesia.

We have been supplying these items for over 10 years through major cementing contractors and up to the present time we have supplied in excess of 500 sets of 4-1/2” and 35 sets of 3-1/2” to a major operator in Indonesia, 100 sets of 2-7/8” to the same operator in Argentina and 400 sets of 3-1/2″ to a major service company for use in China since 2009.

Unique features of the Float Collar and Plugs include the ability to withstand very high pressures to test casing integrity. The plug family also features a positive latch and sealing mechanism preventing any backwards plug movement or backflow in the event of valve failure.

The system can be supplied with optional latch in Calibration Wiper Plug that is designed to accurately calibrate or measure total displacement volume of tubing before displacing cement. When the Calibration Plug latches into the Latch-In Float Collar the rupture disk will burst at 2250 psi +/- 250 psi giving positive indication displacement of volume.

Mechanical & Hydraulic Stage Collar

Seal off plate.
Installed on top of float collar it provides a rubber seal for first stage plug.
First Stage Plug.
Displaces first stage cement.
Opening Plug.
Sometimes called opening bomb. This component is filled with lead and is dropped to open stage collar for second stage cementing.
Closing Plug.
Pumped to displace second stage cement and close stage collar.

Dual Stage Cementing Collar

Allows cement to be pumped in 2 stages thus reducing hydrostatic pressure against lower formations
Usually run when well-bore has formation/s with very low fracture gradient that will not support hydrostatic pressure of full column of cement.

Testing – Float Equipment

Test Rig capable all categories
Flow rates exceeding 30 BPM
Pressure rates exceeding 5000 p.s.i
Temperature rates exceeding 204 oC
Testing performed on regular basis
All tests fully documented
Third party testing accepted

LINER HANGER SYSTEMS OVERVIEW

We have manufactured and sold over 1150 sets of liner hangers since we began developing the product range in 1999.

Our Liner Systems are available in hydraulic and mechanical settings with mechanical or hydraulic releasing tools and can be configured for rotation, reaming or drill down capabilities.

Our liner equipment has been run in many countries around the world including Indonesia, Australia, Papua New Guinea, Pakistan, Bangladesh, India, Libya, Jordan, The Philippines and more.

Today our commitment to innovation, quality and reliability is stronger than ever. Our portfolio includes liner packers, liner hangers, setting tools and accessories and surface cementing equipment.

LINER HANGER SYSTEMS

Setting Sleeves The setting Sleeves provides a connection point for the setting tool to carry the liner in the hole. It can be configured with a tieback receptacle to allow the liner to be extended up the well if required. The Setting Sleeves provide a connection point for the drill string and setting tool to carry the liner load while running the well.

The Setting Sleeves usually will contain profiles for the cement bushing and profiles for rotation of the liner assembly and in most cases includes a tie back receptacle for future liner extension.

Liner Packers Integral Liner Packers are run with the liner hanger to provide a positive liner to casing seal at the liner top. STM manufactures a series of liner packers to meet both low and high pressure needs
The Liner Top Packer is run with a liner completion to provide an additional seal/barrier between the liner casing and the previous casing string.
This effective annular seal reduces the possibility of formation breakdown, fluid losses and gas migration. STM manufactures a variety of liner packer models to fit specific service requirements from low to moderate applications or high pressure and extreme environment models.
Packoffs are available in various material and design to meet the environment and pressure requirements

Liner Hangers Liner hangers provide the ability to suspend the liner inside a previous casing string. STM offers a wide variety of both mechanical set, as well as hydraulic set, liner hangers. Available in single cone and multi cone models, STM hangers are engineered to provide superior performance and dependability in meeting specific well requirements such as high load capacity, fluid bypass area and collapse resistance. Models with rotational capability are also available.

Liner hangers provide the ability to suspend the liner inside a previous casing string. STM offers a wide variety of both mechanical set, as well as hydraulic set, liner hangers.
Available in single cone and multi cone models, STM hangers are engineered to provide superior performance and dependability in meeting specific well requirements such as high load capacity, fluid bypass area and collapse resistance. Models with rotational capability are also available.

Mechanical Set Liner Hangers
Mechanical Liner Hanger has an integral barrel with no internal thread connections for maximum pressure integrity. It is used to suspend a cemented or an un-cemented liner off bottom. STM Mechanical Liner Hanger has a staggered slip alignment which allows extra by-pass and additional hanging capacity. The added by-pass lessens pressure build-up during run-in and cementing, which reduces the chance of damaging the pressure sensitive formations. Limited travel on slips.

Integral barrel provides maximum pressure integrity.
Staggered slip alignment allows extra bypass and additional hanging capacity.
Available with either right-hand or lefthand jay.

Hydraulic Set Liner Hangers
STM Hydro Hanger is a premium Hanger with an integral body and dual cones machined tubing. STM Hydro Hanger is especially effective in deviated wells, because it does not require the manipulation of a mechanical set Hanger. It is set hydraulically by applying pressure to the run-in string. A setting ball is circulated or allowed to gravitate to a ball seat in the PDC Landing Collar or in the LWS (Liner Wiper Plug with a ball seat). Applied pressure acts on the internal piston, moving the slips into a set position.

STM Rotatable Hydraulic Set Hanger incorporates pocket protected slips and piston sleeve protection. These features provide added security for applications where the liner may require rotation or reaming to get to bottom and in high angle or horizontal applications.

STM Rotating Hydraulic Set Hanger is designed to allow rotation of the liner string after setting the hanger. It incorporates a bearing that allows the hanger mandrel to be turned without moving the slips. Rotation of the liner during cementing operation has been proven to enhance mud displacement and cement bond.

Integral barrel eliminates all internal connections above lower nipple
Staggered slip design provides no reduction in fluid bypass area in set position
Full opening bore provides maximum production efficiency

Setting Tools Accesories The setting tool, in conjunction with the setting collar or liner top packer, provide the connection point between the liner and the running string and carry the weight of the liner during deployment. Additional accessories include packer setting dogs and cement packoff bushings. STM setting tools are designed to provide a variety of downhole functions and allow operators multiple operational options when deploying liners. Whether the need is simply to carry the liner in the hole, set right hand mechanical hangers, rotate and/or ream liners or hydraulic release for horizontal wells, STM manufactures tools to meet these requirements.

STM carry a large inventory of Liner running tools that are available on rental or sales basis. Where applicable tools feature rugged drill pipe threads on individual components ensuring that components are easily interchangeable whilst also maintaining the integrity of the drill pipe/running string

Surface Equipment Cement manifolds and other equipment are used at the surface to allow fluids to be pumped into the liner and cement displacement plugs to be dropped. STM’s surface equipment is designed to support tension loads from drill pipe and liner, and to support a Top-Drive Drilling System or a power swivel as the drill string power source.
Cement manifolds and other equipment are used at the surface to allow fluids to be pumped into the liner and cement displacement plugs to be dropped. STM’s surface equipment is designed to support tension loads from drill pipe and liner, and to support a Top-Drive Drilling System or a power swivel as the drill string power source.

Tie Back Equipment STM manufactures a variety of tieback seal nipples and tieback packers to accommodate liner top extension and remedial operations.
STM manufactures a variety of tieback seal nipples and tieback packers to accommodate liner top extension and remedial operations. STM’s tie back equipment is designed to allow existing liners with a receptacle to be extended to the surface or further up hole, and to provide a high pressure seal at the top of a cemented or uncemented liner.

MAP OIL TOOLS FOR SUPPLYING COMPLETION EQUIPMENT

Cement Retainers

Wireline Set Cement Retainers

  • MWR – Wireline Set Sleeve Valve Cement Retainers, High Pressure, Runs on Baker Setting Tool

Mechanical Tubing Set Cement Retainers

  • MMR – Mechanical Tubing set Cement Retainer, High Pressure, Runs on Baker style MMR Setting Tools
  • MSR Mechanical Setting Tool – Mechanical Tubing Setting Tool for MMR Cement Retainers

Cement Retainer Accessories

  • MSS – Stinger Seal Assembly
  • MTC – Tubing Centralizer Stinger Seal Assembly
  • Conversion Kit – Any Model “M” series Cement Retainer can be converted to perform as a Bridge Plug

Bridge Plugs-Permanent

Wireline Set Bridge Plugs

  • MWB – Top Set Bridge Plugs
  • MWB-1 – Converted Sleeve Valve Retainer
  • WRBP-1 – Wide Range Bridge Plug that runs through tubing to set in larger tubing or casing. All plugs now include a 5/8″ Sucker Rod thread to accommodate a centralizer and other tools.
  • WRBP-2 – Wide Range Bridge Plug that runs through tubing to set in larger tubing or casing.

Mechanical Tubing Set Bridge Plugs

  • MMB – Mechanical Tubing set Bridge Plug, use with MSB Mechanical Setting Tool
  • MSB Mechanical Setting Tool – Mechanical Tubing Setting Tool for MMB Bridge Plugs

Hydro-Mechanical Bridge Plugs

  • Hydro-Mech – Hydraulic Pressure and Mechanical Tension set Bridge Plug

Setting Tools

  • MHSB – Hydraulic Setting Tool using a bottom connection same with the Baker 10# or 20# Setting Tool

Wireline Flow Control Tools

  • MX & MXN – X & XN Profile Landing Nipples
  • MF & MR – F & R Profile Landing Nipples
  • MXO, MXA & MXD – X Profile Circulating Sleeves allow communication between the tubing and the casing
  • ML – F Profile Circulating Sleeve allows communication between the tubing and the casing
  • MT-2 – On-Off Tool used in operations that require tubing disconnect and re-engagement without disturbing the packer

Mechanical Set Retrievable Production Packers

  • MAPSET® – Retrievable, double-grip compression or tension-set production packer that can be left in tension, compression, or in a neutral position, and will hold pressure of 7,500 psi max from above or below.
  • MAPSET®-HP- Retrievable, double-grip compression or tension-set production packer that can be left in tension, compression, or in a neutral position, and will hold pressure of 10,000 psi max from above or below.
  • LOCK-SET – Retrievable Packer for production, injection, zone isolation,or remedial operations that holds pressure from above or below while allowing the tubing to be placed in tension, compression,or in a neutral condition
  • MAD-1 – Retrievable tension set Packer, AD-1 type
  • MG-1 – Retrievable Compression Packer, G type
  • MR-3D – Double Grip Retrievable Casing Packer, R-3 type
  • MR-3D LARGE BORE – Double Grip Retrievable Casing Packer, R-3 type
  • MR-3S – Single Grip Retrievable Casing Packer, R-3 type

Hydraulic Set Retrievable Production Packers

  • MFH – Hydraulic set Packer, FH type
  • MFHL – Hydraulic set Packer, FHL type
  • PHP-2-SR – Hydraulic set Packer

Permanent Production Packers

  • Quickset-D – Utilizes Baker style Anchor Latch, Snap Latch or Locator seal system, Permanent Production Packer, High Pressure
  • DGXL – Large ID for parallel string installations or similar applications

Wireline Set Retrievable Production Packers

  • Repeata-B Straddle System
  • Repeata-B – Retrievable Wireline Set Packer
  • Repeata-C – Retrievable Wireline Set Packer, 25% larger slip area than Repeata-B

Unloaders

  • Model H – Multiple acting tool used with set-down packers
  • Model PCU-1 – Used with the PC-1 Service Tool

Thermal Tools and Accessories – 450 Degrees and Higher

  • REPEATA-BSI – Retrievable Wireline Set Packer

Tubing Anchor Catcher

  • TAC-B – Tubing Anchor Catcher simultaneously set in anchoring and catching positions at all times

Tubing Tester

  • Model CSU-1 – Used with the CS-1 Service Tool

Unconventional Intervention

  • CTRBP-1 – Cup Type Retrievable Bridge Plug
  • CTRT-1 – Tubing Running and Retrieving Tool
  • PC-1 – Tension style service tool for shallow depths

Unconventional Completion

  • MAPfrac® FracSleeve – Ball activated frac sleeve designed for use in multi-stage fracturing operations within a horizontal wellbore.
  • MAPfrac® Open Hole Packer – Hydraulically activated open hole packer for use in downhole horizontal or vertical well applications.
  • MAPfrac® Liner Top Packer – Hydraulic set, single trip permanent packer that incorporates a reliable sealing system capable of operating in differential working pressures up to 10,000 psi.
  • MAPfrac® Initiator Valve – Hydraulically activated, differential sleeve that provides the first point of entry and communication to the formation in the completion string.
  • MAPfrac® Circulation-Setting Valve -Open valve located just above the float equipment but below the initiator valve.
  • MAPfrac® FracStart Valve – Serves as the initiation point for communication to the reservoir at the lower most point of the well when run in cemented or open hole casing strings.

Service Tools

  • CS-1 – Compression style service tool with top hydraulic hold down
  • JS®-2A – Heavy duty service tool used in production, stimulation, perforating, gravel packing and testing applications, P110 Mandrel, Coupling and Sub, Carbide Slips and Drag Blocks
  • JS®-3 – Heavy duty storm packer used in production, stimulation, perforating, gravel packing and testing applications, API IF thread connection, P110 Mandrel, Coupling and Sub, Carbide Slips and Drag Blocks
  • MTXT – Quarter-turn, compression set, retrievable service packer that is capable of holding high pressure from above and below
  • MSV-2 – Storm Valve run above JS™-3 to provide well control protection during a temporary abandonment of the well