WO1998009054A1 - Joint d'etancheite gonflable renforce par du ciment destine a une jonction de puits multilateral - Google Patents

Joint d'etancheite gonflable renforce par du ciment destine a une jonction de puits multilateral Download PDF

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Publication number
WO1998009054A1
WO1998009054A1 PCT/US1997/015277 US9715277W WO9809054A1 WO 1998009054 A1 WO1998009054 A1 WO 1998009054A1 US 9715277 W US9715277 W US 9715277W WO 9809054 A1 WO9809054 A1 WO 9809054A1
Authority
WO
WIPO (PCT)
Prior art keywords
sleeve
lateral
junction
elastomeric
wellbore
Prior art date
Application number
PCT/US1997/015277
Other languages
English (en)
Other versions
WO1998009054A9 (fr
Inventor
Rustom K. Mody
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to AU42418/97A priority Critical patent/AU4241897A/en
Publication of WO1998009054A1 publication Critical patent/WO1998009054A1/fr
Publication of WO1998009054A9 publication Critical patent/WO1998009054A9/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/127—Packers; Plugs with inflatable sleeve
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
    • E21B41/0042—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches characterised by sealing the junction between a lateral and a main bore

Definitions

  • This invention relates generally to the completion of junctions between primary and lateral wellbores. More particularly, this invention relates to a new and improved method and device for sealing the junction of a branch wellbore extending laterally from a primary well which may be vertical, substantially vertical, inclined or even horizontal.
  • This invention finds particular utility in the sealing of junctions of multilateral wells, that is, downhole well environments where a plurality of discrete, spaced lateral wells extend from a common primary wellbore.
  • Lateral well drilling and production have been increasingly important to the oil industry in recent years. While lateral wells have been known for many years, only relatively recently have such wells been determined to be a cost effective alternative (or at least companion) to conventional well drilling.
  • a lateral well frequently improves well productivity by several fold.
  • Lateral drilling provides the means for enhancing field economics by accessing and developing reservoirs that would otherwise be uneconomic to develop using conventional drilling and completion practices.
  • Hydrocarbon reservoirs that are ideal candidates for lateral technology are those that are thin and limited in size, multi faulted, or naturally fractured.
  • Other reasons for employing laterals are to address reservoir vertical conformance, oil and gas coning potential and sweep efficiency.
  • Environmental issues, such as the number of drilling sites in sensitive areas can also be addressed with lateral technology.
  • improved field development economics can be achieved in large reservoirs using multiple laterals by improving the productivity of individual wells thereby reducing investment and operational costs.
  • Some wells contain additional wellbores extending laterally from the lateral . These additional lateral wells are sometimes referred to as drain holes and primary wells containing more than one lateral well are referred to as multilateral wells.
  • Multilateral wells are becoming increasingly important, both from the standpoint of new drilling operations and from the increasingly important standpoint of reworking existing wellbores including remedial and stimulation work.
  • lateral well completion and particularly multilateral well completion have posed important concerns and have provided (and continue to provide) a host of difficult problems to overcome.
  • Lateral completion, particularly at the juncture between the primary and lateral wellbore is extremely important in order to avoid collapse of the well in unconsolidated or poorly consolidated formations.
  • open hole completions are limited to competent rock formations; and even then, open hole completions are inadequate in many cases since there is limited control or ability to re-access (or re- enter) the lateral or to isolate production zones within the well. Coupled with this need to complete lateral wells is the growing desire to maintain the size of the wellbore in the lateral well as close as possible to the size of the primary wellbore for ease of drilling and completion.
  • lateral wells have been completed using either slotted liner completion, external casing packers (ECP's) or cementing techniques.
  • ECP's external casing packers
  • the primary purpose of inserting a slotted liner in a lateral well is to guard against hole collapse.
  • a liner provides a convenient path to insert various tools such as coiled tubing in a lateral well.
  • Three types of liners have been used: (1) perforated liners, where holes are drilled in the liner, (2) slotted liners, where slots of various width and depth are milled or wire wrapped along the liner length, and (3) prepacked liners.
  • Slotted liners provide limited sand control through selection of hole sizes and slot width sizes. However, these liners are susceptible to plugging. In unconsolidated formations, wire wrapped slotted liners have been used to control sand production. Gravel packing may also be used for sand control in a lateral well. The main disadvantage of a slotted liner is that effective well stimulation can be difficult because of the open annular space between the liner and the well. Similarly, selective production (e.g., zone isolation) is difficult.
  • ECP's External casing packers
  • This method provides limited zone isolation, which can be used for stimulation or production control along the well length.
  • ECP's are also associated with certain drawbacks and deficiencies. For example, normal lateral wells have many bends and curves. In a hole with several bends it may be difficult to insert a liner with several external casing packers.
  • U.S. Patent 4,436,165 discloses a system for completing multiple lateral wellbores using a dual packer and a deflective guide member.
  • U.S. Patent 2,797,893 discloses a method for completing lateral wells using a flexible liner and deflecting tool.
  • Patent 2,397,070 similarly describes lateral wellbore completion using flexible casing together with a closure shield for closing off the lateral.
  • Patent 2,858,107 a removable whipstock assembly provides a means for locating (e.g., re-entry) a lateral subsequent to completion thereof.
  • Patent 3,330,349 discloses a mandrel for guiding and completing multiple lateral wells.
  • U.S. Patent No. 5,318,122 which is assigned to the assignee hereof and incorporated herein by reference, discloses deformable devices that selectively seal the juncture between the primary and lateral wells using an inflatable mold which utilizes a hardenable liquid to form a seal, expandable memory metal devices or other devices for plastically deforming a sealing material.
  • one method for cementing the junction between the main borehole and the lateral borehole addresses the issue of creating a window in the main (or primary) hole, drilling a lateral wellbore and then sealing the juncture between the lateral and primary wellbores to have the ability to re-enter each lateral wellbore as well as to maintain the option to perform any function that could be done in a single wellbore. For this reason, cemented lateral wellbores are desirable so that normal isolation, stimulation or any other operation can be achieved.
  • a standard whipstock is used to mill out a window in the side of the casing of the primary wellbore at the location where it is desired to drill a lateral wellbore.
  • a standard whipstock is used to mill a window in the side of the casing of the primary wellbore at the location where it is desired to drill a lateral wellbore.
  • the hook liner hanger is run on top of the lateral liner.
  • the liner is run into the main casing and then out through the aforementioned milled window.
  • the hook liner hanger has a pre-machined window, a hook system, and a re-entry system.
  • the running system for the hook liner hanger includes a method of isolating the pre-machined window from the bore of the hook liner hanger. If desired the liner can be cemented in place, using standard cementing techniques commonly used in regular liner placements.
  • the hook liner hanger can be run in various combinations to suit the needs of the wellbore. These combinations can include equipment such as external casing packers, sand control screens, partially cemented liner, fully cemented liner, and liner hanger packers.
  • equipment such as external casing packers, sand control screens, partially cemented liner, fully cemented liner, and liner hanger packers.
  • a tube is attached to the lower end of the liner hanger running tool that extends below the pre-machined window.
  • the annular space between the tube and the Liner Hanger body is sealed, so that the cement does not circulate back through the pre-machined window.
  • the tube can be pulled back above the pre-machined window and then diverted back down through the pre-machined window to clean out the flow path back to the main casing below the milled window.
  • a variation of the hook liner hanger is a version where the formation can be hydraulically sealed from the lateral liner, the lower main casing and the upper main casing.
  • a short section of casing extends from the periphery of the pre-machined window in the hook liner hanger. The end of this section is cut obliquely so that when being run it is possible to run inside the main wellbore casing, yet when landed will still extend from the hook liner hanger.
  • a tie back assembly is employed which will go through the pre-machined window in the hook liner hanger and land in the packer positioned below the window which was initially positioned for the whipstock.
  • the seal system can be of any of the common types such as a packing element, chevron seal system, or an interference seal system.
  • the "hook” liner hanger system includes a “hook” and is run into the wellbore and then through the aforementioned milled window.
  • the "hook” liner hanger system is run into the lateral wellbore until the "hook” hanger locates on the milled window in the main primary wellbore.
  • Inside the "hook” liner hanger system is a tail pipe assembly with adjustable opposing swab cups.
  • the tail pipe assembly carries liquid cement or other fluids as required to inflate external casing packers or other devices as required.
  • the end of the "hook" hanger liner is then plugged to allow the hydraulic set hanger to set by means of applied pressure.
  • An external casing packer located near the end of the "hook" liner hanger system is then inflated to seal the lateral wellbore annular space just below the cementing valve of the "hook” liner hanger system.
  • Opposing "swab-cups” are used to direct fluid to inflate the external casing packer.
  • the tailpipe assembly string is then withdrawn high enough to allow the end of the tailpipe assembly string to be pulled from the lateral wellbore and then lowered into the main wellbore through the premilled window of the "hook" liner hanger system to assist in reducing debris from falling into the main wellbore. While the system does create a good sealed junction it is a difficult process and an easier and more speedy process is always desirable.
  • U.S. Patent number 5,318,122 discloses a number of embodiments employing differing forms and hardenable filling materials.
  • the methods include employing 1) an inflatable mold which utilizes a hardenable liquid like epoxy or cement; 2) expandable memory metal devices; 3) swaging devices for plastically deforming a sealing material; 4)liner seals for sealing between the liner and the primary bore; and 5) side pocket devices to guide a liner into the lateral.
  • All of the prior art devices and methods while performing well for their intended functions are still in need of improvement.
  • a particular area of improvement desired is in the cement at the junction which in present art is employed as both the junction and the seal. This works marginally well and is subject to failure due to limitations in the cement material itself or the ability to place the cement successfully at the junction. More particularly, under the conditions downhole, cement can fail by deteriorating to such an extent that the seal begins to leak thus contaminating the production. Therefore it is desirable to provide alternate junction creating and sealing arrangements which may be more reliable and improved performance under downhole conditions
  • the invention comprises a tubular section including a premachined window and a prebonded double layer elastomeric sleeve.
  • the sleeve may be only elastomeric material or may be reinforced with steel cables, mesh or Kevlar, etc.
  • a valve positioned in the tube advantageously to apply a fluid, preferably cement slurry but any fluid is acceptable, to the space defined by the inner and outer layers of the double walled elastomeric sleeve.
  • a primary wellbore is drilled and cased, a packer is set, a whipstock is placed in communication with the packer and a drillstring is kicked off to mill a lateral window and drill a lateral wellbore.
  • a liner for the lateral borehole is preinstalled and preferably includes a tie back sleeve at the uphole end thereof.
  • the device of the invention is run downhole to the vicinity of the lateral window.
  • orientation of the device of the invention is required in order to ensure that the elastomeric sleeve deploys within the lateral borehole. Orientation is generally accomplished by employing the original whipstock packer with an orientation sub or by employing orientation slots and orientation lugs on various sections of the device of the invention.
  • the elastomeric sleeve In the running position, the elastomeric sleeve is carried inside out within the lumen of the tubing section to which it is bonded. This both protects the elastomeric sleeve during the trip downhole and also minimizes difficulties caused by catching or jamming. It is important to note that although bending is the most preferred attachment of the sleeve to the tool, the only requirement is a pressure tight seal therebetween. This may be accomplished by cables, glue, hose-clamp-like devices, etc.
  • the downhole end of the tubing section of the invention includes a plug so that the tubing may be pressured up upon in order to deploy the double walled elastomeric sleeve of the invention.
  • the sleeve may be of any length and is commonly of 30-40 feet in length. Because of the length, a reasonably significant pressure may be required to fully deploy the sleeve thus making the plug at the downhole end of the tubing section highly desirable.
  • the tubing section further includes a premachined window around which the double layer elastomeric sleeve is bonded. Adjacent the window is a fluid valve such as Baker Oil Tools Part No. 04-30-108-00 which is employed subsequent to deploying the elastomeric sleeve into the lateral borehole.
  • a stabilizer sleeve is next installed into the extended lateral inflatable elastomer sleeve to maintain the sleeve in a desirable position for cementing or otherwise filling.
  • the stabilizer includes a rounded end section to avoid damaging the elastomeric sleeve.
  • the round end section may be of any number of materials including metal, rubber and plastic.
  • the fluid valve is actuated by pressure exerted by the filling fluid itself and facilitates filling the space defined by the two layers of the elastomeric sleeve such that the junction may be sealed. Subsequent to sealing of the junction by inflating the sleeve the downhole end of the elastomeric sleeve is milled to remove both the rubber and fluid in that area (a preferred embodiment includes only a single layer at the end of the sleeve, thus avoiding the need to remove the fluid from that section) and to connect the tieback sleeve on the preinstalled liner to the inflated junction. The stabilizer is sheared off, the whipstock retrieved and the borehole is completed.
  • a high pressure sealed junction is created by the invention which has the additional advantages of sealing around jagged or irregular windows unsuitable for other available systems and provides imcontaminated inflation material, any length of seal desired and increased versatility.
  • FIGURE 1 is a cross-section view of a section of a primary casing with a lateral having been drilled;
  • FIGURE 2 is a cross-section elevation view of a the tool of the invention deposited within the illustration of FIGURE 1 with the inflatable sleeve in the run-in position;
  • FIGURE 3 is an illustration of the invention with the sleeve in the deployed position
  • FIGURE 3A is a cross-section elevation view similar to FIGURE 3 but schematically rendered which illustrates the double layer sleeve more clearly by removing other elements of the invention
  • FIGURE 4 is an illustration similar to FIGURE 3 except that a stabilizer has been kicked-off the guide stock and is supporting the inflatable sleeve for filling with a suitable medium;
  • FIGURE 5 is a cross-section elevation view similar to the foregoing views and sequential thereto in that the stabilizer has been sheared out and removed uphole;
  • FIGURE 6 is a further sequential view where the guide stock has been removed from the well.
  • casing 10 has been drilled out to provide a window 12 and a lateral borehole 14.
  • a lateral liner 17 with tie back extension 16 has been installed in the borehole 14 and a residual packer from the original whipstock is still present downhole.
  • the illustration of FIGURE 1 is that known to the prior art.
  • an inflate housing 20 including a spear retrievable guide stock 22, an uninflated double layered rubber sleeve 24 and a stabilizer joint 26 are positioned appropriately adjacent the window 12.
  • the device of the invention must be properly oriented to carry out the intended operation.
  • the packer 18 provides orientation for the assembly in a known manner.
  • slot and lug systems may be employed to orient the tool in the proper position.
  • the slot and lug type arrangements can be employed to selectively locate or pass by particular laterals thereby providing even more versatility to the invention.
  • the device of the invention is poised for deployment preferably upon hydraulic pressuring from the surface (or by simply inserting the stabilizer, if desired). Subsequent to hydraulic pressurizing, expanded double layered rubber sleeve 24 is visible in FIGURE 3.
  • a rubber end cap is most preferably a single layer of rubber, but may be a double layer to reduce manufacturing costs. The double layer end generally will require removal of the filing medium in that vicinity to connect the stabilizer to the lateral liner. As one of skill in the art will readily appreciate, the length of rubber sleeve 24 preferably is sufficient to engage the tie back extension 16 of lateral liner 17.
  • the stabilizer it is possible, however, for the stabilizer to span any distance there might be between the end of the sleeve and the tieback extension.
  • the tie back extension 16 of lateral liner 17 is placed from 20-40 feet away from the junction between the lateral and the primary casing.
  • the rubber sleeve 24 will preferably be manufactured to span the same distance or as long as reasonably possible while still functioning in the desired manner.
  • isolating cement tool 30 opens a column of cement included inside the tool and allows that cement to be forced through valve 28 to fill the sleeve. Since the stabilizer joint 26 is positioned within the lumen of the sleeve the predetermined ID is maintained. It is important to note that while cement is the most preferred embodiment of the invention, that any other suitable fluid material may be used to fill the sleeve. These materials include drilling fluid, mud, epoxy resins, water or any other fluid. It is not necessary for the fluid to harden or even be hardenable. . Any fluid is capable of filling the sleeve, cement is, however, preferred. Cement is preferred for longevity of the junction.
  • a shear out sub 32 is illustrated which will be employed immediately after inflation is complete.
  • the top half of stabilizer joint 26 along with the isolating cement tool are drawn uphole thus shearing out the shear out sub 32 and allowing the lower portion of the stabilizer joint to remain in the lateral. This is illustrated in FIGURE 5.
  • a spear is then run to pull out the guide stock.
  • FIGURE 6 illustrates the finished junction having unobstructed access to both the lateral and the primary casing.
  • the mechanical integrity of the joint is sufficient to withstand high differential pressures in production.

Abstract

Un packer étanche multilatéral gonflable rempli de fluide uitlise un manchon gonflable (24) à double couche destiné à s'étendre jusque dans la jonction d'un puits multilatéral et à rendre étanche ladite jonction. L'élastomère double couche (ou élastomère renforcé) définit une région de remplissage de matériau de sorte qu'après le déploiement du matériau élastomère double couche dans le puits latéral, on puisse pomper un matériau de gonflage dans le vide ménagé entre les deux couches élastomères et que l'on puisse former ainsi un joint de jonction fiable. Le manchon élastomère double couche est, d'une manière générale, descendu au fond du puits en position inversée (c'est-à-dire, dans la section de tubage de transport), position dans laquelle le manchon est maintenu à l'intérieur d'un segment de tubage, présentant une fenêtre préusinée. La section élastomère à double paroi est liée et/ou scellée au tubage (20) autour de la périphérie de la fenêtre préusinée. Une vanne (28) est également disposée dans le tubage dans une zone située entre la couche intérieure de matériau élastomère et la couche extérieure dudit matériau de sorte qu'on puisse appliquer le matériau de remplissage par la vanne dans une zone désignée. Le manchon élastomère est déployé par application d'une pression sur une bande du tube et il est ensuite maintenu dans la position voulue par un stabilisateur. Dans un autre mode de réalisation, le stabilisateur déploie le manchon. De préférence, on fait passer le stabilisateur après le déploiement du manchon élastomère afin de maintenir sa position pendant le gonflage. Après la procédure de remplissage, on fraise le manchon élastomère au niveau de son extrémité afin de le relier à une garniture latérale préinstallée. L'invention présente des avantages tels que l'amélioration de l'étanchéité sur des fenêtres dentelées ou irrégulières, inadaptées à d'autres systèmes d'étanchéité disponibles. Une opération simple et efficace prolonge la durée de vie utile du joint. On peut citer parmi les autres avantages une jonction non contaminée, une capacité de haute pression et une longueur de joint illimitée.
PCT/US1997/015277 1996-08-30 1997-08-29 Joint d'etancheite gonflable renforce par du ciment destine a une jonction de puits multilateral WO1998009054A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU42418/97A AU4241897A (en) 1996-08-30 1997-08-29 Cement reinforced inflatable seal for a junction of a multilateral

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US2496896P 1996-08-30 1996-08-30
US60/024,968 1996-08-30

Publications (2)

Publication Number Publication Date
WO1998009054A1 true WO1998009054A1 (fr) 1998-03-05
WO1998009054A9 WO1998009054A9 (fr) 1998-06-11

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Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2332919A (en) * 1997-12-31 1999-07-07 Shell Int Research Device for sealing the intersection between a primary and a branch borehole
EP0945586A2 (fr) * 1998-03-24 1999-09-29 Halliburton Energy Services, Inc. Procédé et méthode pour former d'une branche dans un puits
WO2000050733A1 (fr) * 1999-02-24 2000-08-31 Shell Oil Company Renforcement de jonction interne
EP1132568A2 (fr) * 2000-03-10 2001-09-12 Halliburton Energy Services, Inc. Boucher un puits latéral
WO2003069118A1 (fr) * 2002-02-13 2003-08-21 Baker Hughes Incorporated Raccordement multilateral et procede d'installation d'un raccordement multilateral
GB2410759A (en) * 2004-02-06 2005-08-10 Halliburton Energy Serv Inc Multi-layered wellbore junction
US7063163B2 (en) 2003-01-21 2006-06-20 Halliburton Energy Services, Inc. Multi-layer deformable composite construction for use in a subterranean well
US7320366B2 (en) 2005-02-15 2008-01-22 Halliburton Energy Services, Inc. Assembly of downhole equipment in a wellbore
WO2011147021A1 (fr) * 2010-05-28 2011-12-01 Peter Karl Krahn Appareil à vessie extensible en polymère, pour canalisations et puits sous-marins
EP2740883A1 (fr) * 2009-03-03 2014-06-11 Saudi Arabian Oil Company Outil permettant de localiser et de boucher des puits de forage latéraux
WO2018200008A1 (fr) * 2017-04-29 2018-11-01 Halliburton Energy Services, Inc. Procédé et dispositif améliorés destinés à des jonctions étanchéifiées multilatérales
US10689939B1 (en) 2017-02-22 2020-06-23 Mitchell L. White Downhole plug
CN114412423A (zh) * 2021-12-22 2022-04-29 中煤科工集团西安研究院有限公司 一种碎软煤层瓦斯抽采顺层定向钻孔筛管下入装置及方法

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EP0945586A3 (fr) * 1998-03-24 2000-10-11 Halliburton Energy Services, Inc. Procédé et méthode pour former d'une branche dans un puits
WO2000050733A1 (fr) * 1999-02-24 2000-08-31 Shell Oil Company Renforcement de jonction interne
US6253846B1 (en) 1999-02-24 2001-07-03 Shell Oil Company Internal junction reinforcement and method of use
EP1132568A2 (fr) * 2000-03-10 2001-09-12 Halliburton Energy Services, Inc. Boucher un puits latéral
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US6814147B2 (en) 2002-02-13 2004-11-09 Baker Hughes Incorporated Multilateral junction and method for installing multilateral junctions
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EP2740883A1 (fr) * 2009-03-03 2014-06-11 Saudi Arabian Oil Company Outil permettant de localiser et de boucher des puits de forage latéraux
WO2011147021A1 (fr) * 2010-05-28 2011-12-01 Peter Karl Krahn Appareil à vessie extensible en polymère, pour canalisations et puits sous-marins
US10689939B1 (en) 2017-02-22 2020-06-23 Mitchell L. White Downhole plug
WO2018200008A1 (fr) * 2017-04-29 2018-11-01 Halliburton Energy Services, Inc. Procédé et dispositif améliorés destinés à des jonctions étanchéifiées multilatérales
RU2724174C1 (ru) * 2017-04-29 2020-06-22 Халлибертон Энерджи Сервисез, Инк. Усовершенствованный способ и устройство для герметизированных соединений многоствольных скважин
US11111762B2 (en) 2017-04-29 2021-09-07 Halliburton Energy Services, Inc. Method and device for multilateral sealed junctions
CN114412423A (zh) * 2021-12-22 2022-04-29 中煤科工集团西安研究院有限公司 一种碎软煤层瓦斯抽采顺层定向钻孔筛管下入装置及方法

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