OPTSCS
COMPLETION & DOWNHOLE TOOLS
COMPLETION & DOWNHOLE TOOLS
MECHANICAL SET PACKERS
RTTS PACKER ( Retrievable Test Treat Squeeze Packer)
The RTTS packer is a full-opening, hookwall packer used for testing, treating, and squeeze cementing operations. Generally, it is necessary to run the RTTS Packer with an RTTS Circulating Valve assembly, or Model 2 RTTS Circulating Valve assembly for casing sizes 8 5/8 in. and larger. It is also recommended, but optional, to include a safety joint in the string.
The packer body includes a J-slot mechanism, mechanical slips, packer elements, and hydraulic slips. Large, heavy-duty slips in the hydraulic hold down mechanism help prevent the tool from being pumped up the hole. Drag springs operate the J-slot mechanism on ≤ 3 1/2-in. (88.9-mm) packer bodies, while larger packer sizes≥ 4-in. (101.6 mm) use drag blocks. Automatic J-slot sleeves are standard equipment on all packer bodies.
- The full-opening design of the packer mandrel bore allows large volumes of fluid to pump through the tool. Tubing-type guns and other wire line tools can be run through the packer
- The packer can be set and relocated as many times as necessary with simple tubing manipulation.
- Tungsten carbide slips provide greater holding ability and improved wear resistance in high-strength casing. Pressure through the tubing activates the slips in the hydraulic hold-down mechanism.
R-3 PACKER
The Model “R-3″ Retrievable Casing Packer is a retrievable set-down packer that features a large bypass area through the Packer. The bypass area is controlled by a face-seal type bypass valve which is actuated by a 30″ inch stroke mandrel. The Packer is available in a single-grip version for use as a conventional long-stroke production packer and in a double-grip version (with hold-down) for combination production and well stimulation operations.
Features
The double-grip packer, for use where pressure differential from below the packer is anticipated, features an integral hydraulic button-type hold down that is located below the bypass. It also incorporates a unique, built-in “differential lock” which utilizes a balance sleeve actuated by pressure from below the packer. This pressure creates an additional downward force which, combined with set-down weight, helps maintain the force necessary to keep the bypass valve closed.
HYDRAULIC SET PACKERS
PHL Packer ( Perma Latch Hydraulic Retrievable Packer)
The Perma-Lach® PHL hydraulic-set retrievable packer is a high performance, straight shear release packer. The PHL packer has no hold-down buttons, helping eliminate potential leakage from the O-rings. The PHL packer’s optimized OD speeds the run-in process. Setting is achieved by running the packer in on tubing, dropping a ball, or setting a slickline plug and applying pressure. No tubing manipulation is required. To release, pull straight up on the production tubing. Setting pressures can be field adjusted, allowing multiple packers to be run and set during a single trip. Tubing can also be spaced out before the packer is set
APPLICATIONS
- Single or multi-packer production completions
- Can be used as the lower packer in dual completions
- Can be set at predetermined pressures or selectively set in multi-zone completions
- Up to 7,500 psi (51.7 MPa) differential pressure typical
FEATURES
- Optimized OD
- Triple-seal multi-durometer elements
- Shear screws allow operators to vary the setting pressure and release force
- Release mechanism protected from premature shearing
- No mandrel movement when setting
BENEFITS
- Setting pressures can be adjusted in the field
- No tubing manipulation required for setting
- Requires only a straight pull to release
- Multiple packers can be run and set in one trip
- High performance at low cost
Tubing can be spaced out before the packer is set
PERMANENT PACKER
WIRELINE-SET PERMA SERIES® PACKERS
Wireline-Set Perma-Series packers are effective, differential production packers for single or multi-zone completions. These permanent packers may be electric-wireline or hydraulic set on the workstring. They are also designed to leave the packer bore free of all setting devices and maintain a large fluid-bypass area through the packer. Operating envelopes are a graphical representation of the safe combination of differential pressure and applied tubing loads and are available for most Perma-Series packers.
APPLICATIONS
- High formation, unloading differential, or stimulation pressure areas
- Pulling tubing without unseating packers
- High bottomhole temperatures
- Downhole conditions demanding special running clearance
- Twin-flow chemical injections systems
FEATURES
- Upper internal slip design retains the setting force throughout the packer assembly; lower internal slips prevent upward movement of the upper wedge while running
- Internal locking-slip ring aids in fast removal, saving rig time if milling becomes necessary
- Triple-seal multi durometer seal element package is effective at high or low temperatures and pressures
- Metal-to-metal backup shoes with 360° casing wall contact prevent seal element extrusion and offer reliable sealing under ultrahigh pressures
- Contoured C-slip design provides maximum casing contact with uniform slip engagement
- Case-carburized slips provide controlled hardness depth and maximum hardness across tooth section
- Core of slip retains original metallic structure for easy milling
BENEFITS
- Maintains a large fluid-bypass area through the packer
- Saves rig time
Ensures easy milling because the slip core retains its original metallic structure
- Provides flexibility with multiple receiving head and bottom sub options
- Can be adapted for high-pressure/high-temperature applications
SERVICE TOOLS
MECHANICAL SET CEMENET RETAINER ( MMR)
Model MMR Tubing Set Sleeve Valve Cement Retainers are used for secondary cementing operations. These drillable retainers set securely in any hardness casing. A ratchet lock ring stores the setting force in the retainer. The one piece packing element and metal back up rings combine for a superior seal. The case hardened, one piece slips virtually eliminate premature setting, yet can be easily drilled out. They are available for 4 1/2″ through 16″ casing.
- Sets securely in most hardness casing
- Ratchet lock rings secure dynamic setting force
- One piece packing element and rocker action metal back up rings combine for a superior seal
- Compact, easy running
- Pressure balanced sleeve valve is opened and closed by tubing manipulation from the surface for better control
- Set with Model MSR Mechanical Setting Tool
- Can be easily converted to MWR wireline set cement retainer which can be run on Baker wireline setting tool
MECHANICAL SET DRILLABLE BRIDGE PLUG ( MMB)
Model MMB Tubing Set Bridge Plugs are used to isolate zones for temporary or permanent abandonment. These drillable Bridge Plugs set securely in any hardness casing. A ratchet lock ring stores the setting force in the Bridge Plug. The one piece packing element and metal back up rings combine for a superior seal. The case hardened, one piece slips virtually eliminate premature setting, yet can be easily drilled out. They are available for 4 1/2″ through 16″ casing.
- Sets securely in most hardness casing
- Ratchet lock rings secure dynamic setting force
- One piece packing element and rocker action metal back up rings combine for a superior seal
- Compact, easy running
- Pressure balanced sleeve valve is opened and closed by tubing manipulation from the surface for better control
- Set with Model MSB Mechanical Setting Tool
- These bridge plugs can be set on any standard Baker-style mechanical setting tool
- Can be easily converted to MWB wireline set bridge plug which can be run on Baker wireline setting tool
MECHANICAL SETTING TOOLS ( MSR)
Model MSR Mechanical Setting Tools are used to mechanically set MMR Sleeve-Valve Cement Retainers. This tool incorporates both a stinger seal and mechanical setting function. In addition, it has a built-in snap-latch, allowing the tool to be latched into the cement retainer with set-down weight and released with either upstrain or right-hand rotation. The sleeve-valve on the cement retainer is in the open position while being run in the well. When the setting procedure is completed, the ssleeve-valve may be closed by picking up two inches at the tools or opened by slacking off two inches. The snap-latch feature allows the sleeve-valve to be shifted open or closed while the tubing is still anchored to the retainer. Another feature of the tool provides for running the sleeve-valve either open or closed. Normally the valve is run open so the tubing may fill. However, for pressure testing the tubing, while running, the valve can be run closed. Cement Retainers can be set and pressure tested in a single trip.
- Special designed Bow Springs provide positive control and allow each size Mechanical Setting Toos to cover a large casing weight range
- The Upper slips are held in a safe retracted position while running
- Allows users to set, pressure test tubing, and squeeze in a single trip
- Can quickly be configured to set MMB Bridge Plugs
These tools can be used to run a number of competitive brand Baker-style cement retainers
STINGER SEAL ASSEMBLY ( MSS)
Model MSS Stinger Seal Assembly is a tubing conveyed latching seal assembly that is used to operate the sleeve-valve in an MWR Cement retainer previously set on wireline line. The MSS should always be run with a MTC Tubing Centralizer to provide for easier entry into the Cement retainer.
- Provides positive control when the work string is picked up to close the sleeve-valve.
- Re-engages each time the work string is lowered to open the sleeve-valve
- Helps prevent seal from pumping out during pumping operations or tubing testing
- One size operates several sizes of retainers
- Rotate or Snap-out release
- These tools can be used to run a number of competitive brand Baker-style cement retainers
TUBING CENTRALIZER ( MTC)
Model MTC Tubing Centralizer is used to center the tubing and provide for easier entry into an MWR Cement retainer previously set by wireline.
- Provide positive control and allows each size Tubing Centralizer to cover a large casing weight range
- Most parts are common to the MSR Mechanical Setting Tool.
- Allows tubing torque to be transmitted to tools below.
AS RETRIEVABLE BRIDGE PLUG
The AS Retrievable Bridge Plug is a high pressure plug for multiple zone and selective single zone operations such as acidizing, fracturing, cementing and testing. It features a large internal by-pass to reduce swabbing when running and retrieving. The by-pass closes during the plug and opens prior to releasing the upper slips to equalize pressure when unsetting. The by-pass is located directly below the upper slips to help wash debris when the by-pass is open.
This tool can be set in tension, or compression. It can be set shallow in unsupported casing to contain pressure while working on wellhead equipment. It can be set in tension making it ideal for setting shallow to test wellhead equipment and also deep, high-pressure wells.
The ASW Retrievable Bridge Plug is a version of the AS Retrievable Bridge Plug that allows the plug to be set on wireline or with a hydraulic setting tool, and retrieved with tubing. It cannot be reset in the wellbore once it is unset, but it can be pulled, re-dressed and run again. A Wireline Adapter Kit is required for this version.
STORM VALVE (SSCV)
The Subsurface Control Valve (SSC and SSC II) is a combination valve .and backoff joint that allows operators to close in a well that is being drilled without having to pull the workstring. This capability is especially useful in offshore operations when storms are, expected or when surface equipment must be repaired.
The valve eliminates the hazard of leaving pipe standing in the derrick during a storm. Usually a hookwall packer, such as the RTTS Packer, is used with the SSC Valve to support the weight of the workstring.
The packer seals inside the casing (surface pipe or intermediate casing string), and the SSC Valve seals the inside diameter of the workstring. Because the SSC Valve includes a back-off connection, the workstring above it can be removed and reconnected when operations resume.
When the tool is operated from a floater-type rig, a bumper sub or slip joint should be inserted in the workstring above the SSC Valve.
The SSC Valve
- Saves rig time
- It is easy to operate
- Tests wireline valves during drilling operations
- Increases the, crew’s safety
The SSC II Valve
- Requires only right-hand rotation to release the workstring from the valve
- Requires no rotation to reattach the workstring to the valve
- It is easy to operate in an emergency
- Increases the rig crew’s safety By opening and closing the valve, the operator can check for pressure buildup before unsetting the packer.
- The SSC II Valve can circulate large volumes of drilling fluids to recondition the mud system before the packer and valve are removed and normal drilling operations resume.
COMPLETION ACCESSORIES
LANDING NIPPLES
Landing Nipples and Lock Mandrels , Selective by Running Tool The landing nipples and lock mandrels that are selective by running tool consist of Otis® X® and R® series landing nipples and lock mandrels. The Otis XN® and RN® no-go landing nipples and no-go lock mandrels are also available.
Otis X and R Landing Nipples and Lock Mandrels Otis X and R landing nipples are run into the well on the completion tubing to provide a specific landing location for subsurface flow control equipment.
The common internal profiles of these landing nipples make them universal. The Otis X landing nipple is used in standard weight tubing.
The Otis R landing nipple is typically used with heavyweight tubing. The completion can have as many selective nipples with the same ID in any sequence as desired on the tubing string. This versatility results in an unlimited number of positions for setting and locking subsurface flow controls. The flow control, which is attached to the required Otis X or R lock mandrel, is run in the well via the selective running tool on slickline. The slickline operator using the selective running tool can set the flow control in any one of the landing nipples at the desired depth. If this location is unsatisfactory or if well conditions change, the flow control may be moved up or down the tubing string to another nipple location. These operations can be done by slickline under pressure without killing the well. Otis XN and RN No-Go Landing Nipples and Lock Mandrels This equipment is designed for use in single nipple installations or as the bottom nipple in a series of Otis X or R landing nipples. These landing nipples have the same packing bore ID for a particular tubing size and weight. Otis X and XN landing nipples are designed for use with standard weight tubing. Otis R and RN landing nipples are designed for use with heavyweight tubing. (The N designates no-go nipples.)
APPLICATIONS
- Gauge hangers for bottomhole pressure/temperature surveys
- Positive locator for straddle systems
- Plugging under pressure
- Almost unlimited locations for setting and locking subsurface flow controls
FEATURES
- Landing Nipples
- Large bore for minimum restriction
- Universal nipple with one internal profile
- Lock Mandrels
- Retractable locking keys
- Locks designed to hold pressure from above or below or from sudden reversals
- Extra large ID for higher flow volumes
- Optional Holddown
- Interference holddown for smaller locks
- Shear pin holddown for larger locks
SLIDING SLEEVE DOORS ( SSD)
The DurasleeveTM is , new non-elastomeric circulation/production sleeve. It features non-elastomer engineered composite material (ECM) as the seal material. It has contained O-rings and Vee packing made of elastomeric (rubber like) seal components. A circulation/production sleeve (sometimes called ‘sliding sleeve’ or just ‘sleeve’) is a device which is made up as part of the tubing string. During installation into the tubing string, DO NOT torque across the device. The primary function of this device is to provide controlled communication between the tubing and tubing/casing annulus. By use of wireline from the surface, the sleeve may be ‘opened’ or ‘closed’ to gain communication or to shut off communication between the tubing and tubing/casing annulus. The ‘sleeve’ contains an inner sleeve which is capable of being ‘shifted’ up or down using the proper wireline tool. The up or down shifting of the inner sleeve opens or closes the Dura sleeve depending on the sleeve design. There are those which open by upward movement of the inner sleeve and others which open by moving the inner sleeve downward.
There are several wireline positioning (shifting) tools available to open/close ‘sleeves’. The type of positioning tool used depends on several considerations- how many ‘sleeves’ are in the tubing string, which ‘sleeve’ is to be worked on, and which direction the inner sleeve is to be moved.
As mentioned, the primary function of the Dura sleeve is to provide controlled communication between the tubing and the tubing/casing annulus.
A few functions provided by this capability include:
- Killing the well. If the annulus contains heavy weight kill fluids, the DurasleeveTM can be opened allowing the kill fluid to enter the tubing string and assist in killing the well.
- Produce multiple zones. If more than one production zone is present in a well, ‘sleeves’ can be opened or closed to produce any one of the zones.
- Change out well bore (annulus) fluids after well completion.
- In rare cases, ‘sleeves’ are used for gas lift injection purposes.
The DurasleeveTM typically contains a landing nipple profile (usually X or R) in the top sub into which a lock mandrel and plug can be placed by means of wireline. This nipple profile can be used for similar purposes as an ordinary landing nipple.
WIRELINE REENTRY GUIDE
Wireline reentry guides are used for safe reentry of wireline tools from the casing into the tubing string. Threaded on the top end only, they attach to the bottom end of the production string and are designed with a beveled guide and a full open internal diameter.
