H and H Table of Contents Description They are also frequently used as a permanent squeeze or testing packer, or as a bridge plug. This document is and contains unpublished, copyrighted and confidential information of Baker Hughes, and is revealed for limited purposes only. This document is the property of Baker Hughes and is to be returned to Baker Hughes on request and may not be reproduced, used or disclosed to persons not having a need to know consistent with the purpose of the document, without the written consent of Baker Hughes.
It may also be used in any application that includes the use of an upstrain-type releasing device. The permanent packer features an enlarged alternate-upper sealbore above Japanese celebrity wallpapers packer. In the case of a retrievable sealbore packer, the mill-out extension will accommodate the mandrel and catch sleeve of the retrieving tool. H and H Baker model db permanent paker blanking plug; Baker Hughes low-control seating nipple with blanking plug; hydraulic-setting devices Product Family Nos. Full opening bores allow the passage of perforating guns used to perforate a zone below for testing. Please specify thread when ordering. Used under trademark license. By Camilo Cajiao. And because the AD-1 is tension-set, it is ideally suited for shallow wells where set-down weight is not available.
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In this case, a temporary plugging device is used in conjunction with the packer to allow the well pressure above the packer to be bled off once it is installed. BHGE and C3. The tension packer is suited for applications in which pressure below the packer is always greater than the annulus permnent at the tool. The shear-release value must not be set too high so that it will not be beyond the tensile capabilities of the tubing string, yet it must be high enough so that the packer will not release prematurely during pefmanent of the planned operational modes over the life of the completion. The dual packer allows the simultaneous production permanennt two zones while keeping them isolated. Let's stay in touch. H View Details. Last Name:. The tension packer does not have an equalizing or bypass valve to aid in pressure equalization between the tubing and annulus to facilitate the retrieval of the packer. The Baker model db permanent paker is Baker model db permanent paker run and set on electric wireline. Dv Added Items. Canada Remove This Item.
- Depending on the unique attributes of your completion configuration, our technicians will help you choose the right packer to create a tight barrier that holds firmly in place—even in challenging wellbore geometries.
- No matter the challenge—whether your well is a simple, single-zone completion or a complex, deepwater multilateral—you can count on us having the right packer for your job.
Call Us Today! Log In. Facebook Twitter Linkedin. These packers assist in the economical operation of a variety of completion and production jobs. These are designed to accommodate seal bore extensions used in deep wells requiring a longer seal bore interval. Seal Nipples are available with either automatic square-thread latch or locating shoulder. These packers can be used as test tools.
Full opening bores allow the passage of perforating guns used to perforate a zone below for testing. If the zone proves to be non-productive, the packer can be used as a squeeze tool. The packers are designed to provide high-impact resistance and a dependable seal.
The high quality packing system will conform to the casing and close off any extrusion of rubber, as the packer is set, even at high temperatures and pressures. The two models carry different pressure ratings noted later in this document. R22 is the designation for standard service that ACT puts on the equipment listed below. OD Wt. OD Thd. Seal Bore Part No.
Size Size ID Thru 4. Specify when ordering. Size Size ID Thru 5.
Show search Menu. Once the packer is installed, a sealing device is attached to the end of the production tubing and connected to the packer downhole to form a seal. First Name:. This seldom presents a problem with the tension packer, because the packer is run at relatively shallow depths, and differential pressures across the packer during retrieval should be low. Patton, L.
Baker model db permanent paker. Navigation menu
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MODEL 'D' & 'F' PERMANENT PACKERS | American Completion Tools
Log In Sign Up. Packer Systems Catalog. Manuel Sosa. Today, when your projects push the edge of the completion technology envelope, you can count on our packers to reliably deliver unsurpassed service, performance, and value.
Research and development focus on cased and open-hole completion technologies, iber optics, and downhole electronics, nanotechnology, and materials science. The ft In addition to the CTI, and other facilities in Houston, research and engineering for completions products and services is conducted in Broken Arrow, Oklahoma, and Aberdeen, Scotland. Description Page Family No.
Description Page H Casing Scraper Description Page H Sealbore Extension However, there is no pressures, providing they are always contained within a sealbore. Effective sealing in downhole environments sealbore. Several sets of identical seal systems can be combined to create a seal stack with redundant seals.
This action is known as unloading. Sealing systems using contained premium elastomers are offered as a chevron- or v-ring-type seal stack. Under rapid decompression, the elastomeric seals in these units may be susceptible to explosive decompression, however, explosive decompression does not occur while seals are in service.
The software performs a series of calculations that allow the user to determine the magnitude of forces, stresses, and changes in length of tubulars suspended in wells. The program enables the user to select the method of setting the packer, pick between single or dual string completions, import survey data, and generate three dimensional representations of the well.
Version 2. X For injection and disposal wells, list all liquids and gasses injected. If well will initially be used as a producer, please ill out two forms. Oxygen ppb is critical for injection well. Rating a production packer in critical completions. Ensuring all load combinations fall inside the terms of differential pressure alone does not suficiently describe the region formed by the curves conirms that the equipment is adequate packer's performance limits.
To accurately measure and compare the for the combined loading conditions. Some conditions outside the packer's performance capabilities, under all possible loading conditions.
Others may prevent the packer numerical stimulation techniques, including inite element analysis, from functioning as designed, while retaining pressure integrity. Various mechanical-set styles are available; this normally includes a single packing element system without a bypass or unloader.
These styles offer the simplest means of isolating the casing annulus. A common single-zone well completion, at moderate depths and pressures, will require a compression-set packer. It will include features suited for the well's current lowing condition and future pumping treatments of that zone.
This type of packer is limited to moderate treating pressures because of their packer-to-tubing tension loads, which can be seen during treating procedures. In higher-bottomhole- temperature wells, effects of treating pressures and cooling of the tubing string must be evaluated to ensure the tension forces do not force the internal bypass open.
Besides wellbore conditions, these operations can create tremendous dynamic loads on the sealing system and mechanics of the packer. The tool is often subjected to high-bottomhole-setting temperatures and pressures. High- tensile loads are transmitted to the packer as the tubing string is cooled through the duration of pumping operations.
The packer is also subjected to extreme reversals of pressure differential. Although various methods address this need, it is often beneicial to use a wireline-set retrievable packer as a means of temporary plugging the well. This enables the well to resume production quickly following the operation.
The alternative is to snub tubing in the hole or kill the well. Typical installations involve wireline deployment, permitting setting in pressurized wells.
With a wireline- retrievable plug installed in the L seal nipple proile before deployment, the packer serves as a temporary bridge plug. When the plug is removed well production is restored. Completions with hydraulic-set packers require a means of temporarily plugging the tubing, typically a wireline-entry guide with pump-out plug, ball-seat sub, or a proile-landing nipple for use with a wireline-retrievable plug.
Pump pressure applied down the tubing string provides actuation of the packer's setting mechanism. These packers can be either permanent or retrievable. The retrievable versions normally include a shear release, requiring only straight pull on the packer.
The tubing string can be positioned into the sealbore packer in two ways: a locator tubing seal or anchor tubing seal assembly. The locator tubing seal provides a high-pressure seal between the packer and tubing and Safety Valve allows movement of the seals during well operations. The inclusion of extra tubing-seal units below a locator, as shown in the accompanying hookup drawing, compensate for tubing movement by traveling through the packer bore and the sealbore extension.
The anchor attaches the tubing string to the packer, restricting motion of the seals and transmitting tubing forces through the packer to the casing. The anchor is released by right-hand rotation. The packer and tailpipe assembly are run in and set either on wireline or tubing, with a setting tool. Both methods permit thru-tubing perforation, while pressure is maintained Signature DB Retainer Production Packer for safety and langed up displacement of well luid through the sliding sleeve.
Pressure and temperature recording instruments can be set in the lower seating nipple without restricting the low path, while protecting the instruments from low turbulence and vibration. A blanking plug installed in the L seal nipple proile converts a DV production packer into a temporary bridge plug that is carried in and set on electric line or drillpipe in a single run.
The system enables an operator to perforate and stimulate an upper zone, while isolating a lower zone. Sealbore packers used for workovers are often subject to problems caused by debris settling in the packer and tailpipe while the tubing is removed. If wireline-conveyed blanking plugs have been used to control the well or to protect the formation, recovery problems can be experienced due to the debris on the plug.
When the tubing is run back into the well, the sand can be washed away as the standard L washover shoe is engaged. This provides clear access to the blanking plug, which can be removed by conventional methods. Typically, a granite packer, which is a no-body-movement, hydraulic-set permanent packer, is stabbed into a liner top.
Using this coniguration enables completion of the well with a minimally compromised ID, due to the elimination of restrictions in the production string, speciically the nipple proiles. The safety valve, if present, is the only restriction in the system. The combination of a hydraulic-set permanent packer, with a polished- bore receptacle PBR , is a lexible and common well completion method.
This completion design allows the entire completion Polished Bore to be run in one trip, while permitting displacement of wellbore luids and Receptacle langed-up packer setting. The permanent packer features an enlarged alternate-upper sealbore above the packer. An anchor tubing seal assembly is latched into the alternate bore with a PBR extending above it. Thus, low area, equivalent to the packer's lower bore, can be maintained. The PBR allows for extreme tubing movement during well operations.
During the initial completion phase, both packers are installed above the target zones. The lower zone is then perforated and the well is put on production.
The zones can also be commingled at any time during the life of the well. This example shows a Top No-Go Nipple completion using permanent-or retrievable-sealbore packers and locator tubing-seal assemblies.
Selectivity is accomplished by opening Retainer Production Packer and closing the sliding sleeve between the packers. Blast joints located adjacent to producing zones resist the erosive forces of produced luids. The completion also allows commingling of zones or separate production, isolation, testing, or individual stimulation of zones. Sliding sleeves between the packers make this range of selections possible.
Lower packers isolate the lower payzone, with production directed through the packer's seal assembly and out through the long- string side of a parallel low tube. Flow from the upper zone is produced Safety Valves through the bore of upper packers, directed into the short-string bore of the Model A parallel-low tube.
This installation requires an alternate upper sealbore in the top packer to provide suficient diameter for the dual-low paths, while also providing a seal area to isolate upper-zone pressure at the packer.
Hydraulic- set packers permit langed-up setting, eliminating the need for wireline. Tubing nipples positioned below each packer provide the temporary plugging required to set the packer or as required through the life of the well. A sliding sleeve, positioned on the long string above the lower Safety Valve packer, enables circulation or spotting of luids for upper-zone treatment or production of the upper zone through the long string.
As required in offshore completions, subsurface safety valves installed on both strings Safety Valve above the dual packer provide automatic shut-in if there is damage to the tree or tubing strings above the packer.
Multiple payzones can be perforated in the initial completion procedures and isolated when required without future rig intervention. Sliding sleeves can be opened to produce from either tubing string, between the dual packers. Landing nipples positioned below the lower-dual Telescoping Swivel Sub packer and lower single-string packer provide the temporary plugging CMD Sliding Sleeve required during packer-setting procedures. This type of completion coniguration offers long-term lexibility for changing well conditions, while providing a completely retrievable completion system.
The Premier removable packer has been developed by merging hydraulic and hydrostatic Safety Valve technologies into a design platform that reduces rig time and minimizes the risk associated with standard well setting methods.
The proven Striker system is a device that generates packer setting force from hydrostatic well pressure. As a Seating Nipple secondary or contingent setting method, this packer can also be set by hydraulic pressure.
Removal on the production string is accomplished by cutting the mandrel with a chemical or mechanical cutting tool. The Premier system offers high-performance and multiple removal options for high-cost interventionless completions. Technology in this ield is growing at a rapid pace in an effort to reach production quicker and reduce overall costs.