Abstract: A method for producing gas from a well including a wellbore extending from a surface into a subterranean formation, wherein the well also produces liquid, the method including: (a) producing gas from a production zone in the subterranean formation through an annulus extending within the wellbore at a first velocity that is greater than a critical velocity, and (b) pumping liquid through a liquid tubing string after (a) to reduce a level of the liquid within the wellbore. The method also includes: (c) shutting in the annulus after (a) after the first velocity decreases below the critical velocity, wherein the annulus has a first cross-sectional area and the first production string has a second cross-sectional area that is less than the first cross-sectional area, and (d) producing gas from the production zone through the first production tubing string after (c) at a second velocity being greater than the critical velocity.

Abstract: Isolation systems for use in a wellbore include two or more tubular segments and at least one coupling assembly. The at least one coupling system is adapted to couple the first and second tubular segments together. The at least one coupling system is further adapted to block at least a portion of the wellbore annulus. The at least one coupling system is further configured as a leaky isolation assembly to separate the wellbore annulus into at least two isolated zones when disposed in the wellbore. At least one isolation zone has at least two outlets including a first outlet through an opening into the tubular and a second outlet past the leaky isolation assembly. The isolation system is configured to provide the isolation with hydraulics during well operation that preferentially drives fluids through the first outlet and at least substantially prevents fluid from passing the isolation assembly.

Abstract: An apparatus and associated method for controlling a flow of a fluid between a wellbore tubular and a formation may utilize a particulate control device positioned external to the wellbore tubular and a flow control device having a retrievable flow restriction element that controls a flow parameter of a fluid flowing between the particulate control device and a bore of the wellbore tubular. The flow control device may be re-configured in the wellbore and/or be used to inject a fluid into the formation.

Abstract: A system for use with a well having multiple zones can include multiple well screens which filter fluid flowing between a tubing string and respective ones of the zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the tubing string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the well screens. A tubing string for use in a subterranean well can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen.

Abstract: A method of servicing a subterranean formation comprising providing a wellbore penetrating the subterranean formation and having a casing string disposed therein, the casing string comprising a plurality of points of entry, wherein each of the plurality of points of entry provides a route a fluid communication from the casing string to the subterranean formation, introducing a treatment fluid into the subterranean formation via a first flowpath, and diverting the treatment fluid from the first flowpath into the formation to a second flowpath into the formation.

Abstract: Multiple zones of a wellbore are gravel packed and fractured in the same run-in trip into a wellbore. An insert string is subsequently extended into the wellbore in order to regulate and monitor production from each zone. Control lines located within the insert string and also along the sand face allow operators to monitor production operations, including measuring fluid and well environment parameters at each point within the system. One or more control and data acquisition modules included in the insert string are able to locate and move corresponding flow control devices arranged within respective sand screens adjacent each zone. Adjusting the position of the flow control device with a corresponding control and data acquisition module serves to choke or otherwise regulate the production flow rate through the sand screen, thereby allowing for the intelligent production of hydrocarbons from each zone.

Abstract: A technique facilitates sidetracking by eliminating one or more trips downhole. The technique comprises delivering a sidetracking system downhole into a wellbore, and utilizing a component of the sidetracking system to grip a wall of the wellbore. The sidetracking system may comprise a whipstock assembly and a running/stinger assembly in which the stinger assembly is designed for disconnection from the whipstock assembly after delivery downhole. After disconnecting the stinger assembly, the sidetracking system enables delivery of cement slurry down through the stinger assembly to form a cement plug at a desired location.

Abstract: Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies.

Abstract: An arrangement for directing a fluid flow or a tool transported in a fluid flow in an under water structure includes plural flow line arrangements each including at least one flow line, and at least two distribution devices to be varied between at least two positions. One distribution device connects at least two flow arrangements providing for the selection of the fluid flow pattern directing the fluid through the distribution devices and the flow arrangements depending on the position of each of the distribution devices. A method directs a fluid flow or a tool transported in a fluid flow.

Abstract: A junction can be isolated from fracturing pressure using a liner extending from a one bore through a junction into a lateral bore, where at least a portion of the liner is retrievable from the lateral bore prior to completion of wellbore construction. The junction may be temporarily isolated from high pressure, such as high pressure from a fracturing stimulation process. Part of the liner can be retrieved using a disconnect mechanism or technique.

Abstract: Disclosed are systems and methods of producing from multiple production zones with a single trip multi-zone completion system. One single trip multi-zone completion system includes an outer completion string having at least one sand screen arranged thereabout and being deployable in an open hole section of a wellbore that penetrates at least one formation zone, a production tubing arranged within the outer completion string and having at least one interval control valve disposed thereon, a control line extending external to the production tubing and being communicably coupled to the at least one interval control valve, and a surveillance line extending external to the outer completion string and interposing the at least one formation zone and the at least one sand screen.

Abstract: A remediation process that a employs improved quantitative method(s) of estimating of the volume and/or mass of contaminant in the subsurface, removal and or in situ degradation of the contamination using subsurface pulsing treatment (“SPT”) technology, and evaluation of the degree of remediation by re-applying the quantitative contaminant evaluation methods. The process uses SPT technology with the addition of a vacuum or sub-atmospheric pressure to an extraction well in order to create a push-pull effect to remove free contaminant or residual in conjunction with the pressure wave driving force created in the excitation or excitation well. The process can quantitatively measure the amount of residual contaminant, which up until now has not been possible or tractable using in situ methods, as well as measure the amount of residual that can be removed by SPT.

Abstract: A method for completion of a lateral wellbore using a high pressure multibore junction assembly, which comprises a tubular main leg and a tubular lateral leg. The tubular main leg is secured within a main wellbore and the tubular lateral leg is positioned through a lateral wellbore. The tubular main leg and the tubular lateral leg may be stabilized relative to each other as the multibore junction assembly is lowered into the main wellbore.

Abstract: A junction can be isolated from fracturing pressure using a liner extending from a one bore through a junction into a lateral bore, where at least a portion of the liner is retrievable from the lateral bore prior to completion of wellbore construction. The junction may be temporarily isolated from high pressure, such as high pressure from a fracturing stimulation process. Part of the liner can be retrieved using a disconnect mechanism or technique.

Abstract: A pipe setting tool includes a tool shaft, a coupler mounted on a first end of the tool shaft, and a tool sleeve affixed to the tool shaft defining a space therebetween. An outside diameter of the tool sleeve ensures close conformity to a borehole to position a geothermal pipe mounted thereto in close proximity to the outside diameter of the borehole. A moveable seal cap may be mounted on the tool shaft, moveable between a first position spaced-apart from the tool sleeve during down-hole movement of the tool to permit fluid flow through the space and a second position against the tool sleeve during up-hole movement of the tool to establish a seal with the tool sleeve to prevent fluid flow through the space. A second end of the tool shaft may receive a pipe hook to attach a geothermal pipe to the pipe setting tool.

Abstract: A multilateral completions assembly having selectively isolated lateral legs during hardware installation. The assembly includes a variety of isolation sleeves disposed interior of the main bore casing and adjacent corresponding pre-located windows through the casing. Thus, lateral legs may be sequentially created through the formation at each window in a manner that allows for follow-on isolation. As a result, fluid losses from newly formed legs may be avoided during completions operations. That is, as each leg is formed it may also be isolated in advance of forming of the next leg thereby enhancing the efficiency of completions operations as well as follow-on production.

Abstract: A wellbore system and a method of forming the wellbore system, where the wellbore system is made up of a primary wellbore that is disposed entirely above a producing zone and lateral wellbores that extend from the primary wellbore into the producing zone. By penetrating the producing, or target, zone with the lateral wellbores, fractures in the target zone can be better avoided thereby increasing the potential amount of recoverable hydrocarbon. Optionally, wellbore systems are included that have more than a single primary wellbore. Further disclosed is a method of maximizing wellbore production by selectively blocking designated lateral wellbores in which water or other non-hydrocarbon fluid is detected.

Abstract: A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Abstract: A method of producing liquid hydrocarbons from a subterranean formation can include flowing the liquid hydrocarbons from the formation through at least one valve, and increasingly restricting flow through the valve in response to pressure and temperature in the formation approaching a bubble point curve from a liquid phase side thereof. A method of producing gaseous hydrocarbons from a subterranean formation can include flowing the gaseous hydrocarbons from the formation through at least one valve, and increasingly restricting flow through the valve in response to pressure and temperature in the formation approaching a hydrocarbon gas condensate saturation curve from a gaseous phase side thereof.

Abstract: A first tubular member disposed within a second tubular member, and an annulus formed therebetween. The second tubular member can have a first and second packer disposed about an outer diameter thereof. The first packer can have a slip. The packers can be in fluid communication with the inner diameter of the first tubular member via one or more flow ports formed through the first tubular member. One or more inflow control devices can be disposed between the packers.

Abstract: A system and a method for controlling the flow of fluid in a branched well from a reservoir (29), the system including a completed main well (27) having at least one uncompleted branch well (25), an annulus (24) defined between the reservoir (29) and a production pipe (1) of the completed main well (27) and at least two successive swell packers or constrictors (26) defining at least one longitudinal section of the main well (27) and within which at least one branch well (25) is arranged, and including at least one autonomous valve (2) arranged in the longitudinal section of the main well (27) defined between the two successive swell packers or constrictors (26). The uncompleted branch wells (25) are provided to increase the drainage area, i.e., maximum reservoir contact (MRC).

Abstract: Systems and methods usable to operate on a plurality of wells through a single main bore are disclosed herein. One or more chamber junctions are provided in fluid communication with one or more conduits within the single main bore. Each chamber junction includes a first orifice communicating with the surface through the main bore, and one or more additional orifices in fluid communication with individual wells of the plurality of wells. Through the chamber junctions, each of the wells can be individually or simultaneously accessed. A bore selection tool having an upper opening and at least one lower opening can be inserted into the chamber junction such that the one or more lower openings align with orifices in the chamber junction, enabling selected individual or multiple wells to be accessed through the bore selection tool while other wells are isolated from the chamber junction.

Abstract: Systems and methods for improving functional access to subterranean formations that include a well, which includes a casing string having at least one casing conduit that extends and provides a hydraulic connection between a surface region and the subterranean formation. Performing a plurality of downhole operations utilizing a casing string that constitutes a plurality of hydraulic pathways between the surface region and the subterranean formation. In some embodiments, the plurality of downhole operations may be simultaneous operations and/or may be associated with at least one of a plurality of operational states including a drilling state, completing state, stimulating state, producing state, abandoning state, and/or killing state. In some embodiments, systems and methods may include a plurality of production control assemblies to control and/or monitor the downhole operations.

Abstract: An apparatus having a modular support frame with a top deck. The top deck has a passage therein. A tower is mounted on the top deck. A moveable plate and a track are positioned within the passage. The movable plate is slidingly attached to the track. A support rotary table is disposed within the modular support frame and suspends jointed tubulars. A coiled tubing injector head interface plate is operatively attached to the movable plate, and positioned over the first aperture of the movable plate. The first aperture is positioned over the well in a first position. A rotary table is positioned over the well in a second position. The apparatus is mounted on a transport vehicle in a transport position and moved to a well site. A lifting mechanism lifts the apparatus into an upright position. Well intervention work is conducted with coiled tubing and jointed tubulars.

Abstract: Systems and methods for fracturing a formation are provided. A method includes generating a subsurface model including the production formation and a zone proximate to the production formation. A number of scenarios are simulated in which a volumetric change is created in the zone proximate to the production formation. A scenario is selected from the plurality of scenarios to stimulate the production formation. The scenario is performed to create a fracture field in the production formation.

Abstract: Systems and methods are described for fracturing a production formation. A method includes drilling a well into a zone proximate to a production formation, and increasing a volume of the zone through the well in order to apply a mechanical stress to the production formation.

Abstract: A location and orientation assembly suitable for use in a multi-lateral wellbore may include a coupling portion, an upper muleshoe, a muleshoe spacer and a bottom muleshoe. The bottom muleshoe may connect to the coupling portion through a threaded connection. A method for locating and orienting in a multi-lateral wellbore includes providing a locating and orientation assembly. In the orientation assembly a coupling portion is provided and an upper muleshoe is inserted into the coupling portion. A muleshoe spacer is inserted into the coupling portion so as to matingly contact the upper muleshoe portion. Part of a bottom muleshoe is inserted into the coupling portion so as to matingly contact the muleshoe spacer. The coupling portion is jointed to the bottom muleshoe by a threaded connection.

Abstract: A technique enables an efficient, dependable approach to gravel packing lateral wellbores. The technique employs alternate path gravel placement technology which includes alternate path equipment deployed along a gravel pack screen positioned in an open hole lateral wellbore disposed above a lower lateral wellbore. A crossover system is positioned in the lateral wellbore, and the alternate path is provided by connecting a shunt tube or other appropriate alternate path equipment to the crossover system. A flow of gravel slurry is directed along an exterior of the gravel pack screen through the alternate path equipment to enable uniform distribution of the gravel pack along the gravel pack screen.

Abstract: A stand-alone frac liner that allows for fracturing of multiple lateral legs of a multilateral well on a single call out and rig-up of fracturing equipment. Tools and techniques are provided that include setting multiple stand-alone frac liners in multiple lateral legs of the multilateral well. The liners may rest in the legs physically untethered to surface equipment. Thus, a single call out of a frac string tubular and associated equipment may be used to frac the lateral legs in sequence from one leg to the next. This may be achieved without the requirement of removal of the tubular from the well or disconnect of surface fracturing equipment between the lateral fracture applications. Thus, a considerable amount of expenses associated with time and manpower may be saved.

Abstract: Selective placement of conformance treatments in multi-zone well completions. A method includes injecting a relative permeability modifier into a zone and optimizing a ratio of desired fluid to undesired fluid produced from the zone, including adjusting at least one flow control device between fully open and fully closed configurations. Another method includes injecting a relative permeability modifier into multiple zones, one at a time, via respective flow control devices, and then producing fluid from each of the zones. Another method includes identifying which of the zones to treat by, for each of the zones: a) closing flow control devices corresponding to the other zones, and b) evaluating fluid produced from the zone; and injecting a conformance treatment into the zones identified as the zones to treat.

Abstract: Methods and systems for gas sequestration are provided. The systems include a porous storage reservoir containing a dense fluid; a first tubing string, configured to provide and inject a gaseous emissions (GE) stream at or near the top of the porous storage reservoir above the base portion of the porous storage reservoir; and a second tubing string configured to withdraw the dense fluid from the base portion of the porous storage reservoir. In some embodiments, the first and second tubing strings may be encased in a single well bore and may include measurement and control equipment for pressure management of the injection locations. The withdrawn dense fluids may be re-injected into an overlying porous reservoir or may be sent to the surface for treatment. Methods are provided for injection of GE and withdrawal of dense fluids for safe, long term gaseous sequestration of significant portions of carbon dioxide (CO2) and associated gases (gaseous emissions, GE).

Abstract: Drilling a sidetrack wellbore out of the side of an existing wellbore utilizing a drillable billet having a path formed in the billet to lead a bi-centered drillbit to kick-out from the wellbore and form a sidetrack wellbore. The bi-centered bit is arranged for the lands of the pilot section to follow the path of the billet while the wings of the ream out a portion of the billet and also ream out the earth to form the full dimension sidetrack wellbore. The bi-centered bit is used to drill the sidetrack wellbore to the target zone so that the entire drilling process extends from the existing wellbore to the target zone without a mandatory withdrawal of the drillstring from the wellbore.

Abstract: The present invention relates to a system, apparatus, and method provided to selectively produce petroleum fluid from multiple production zones well. The apparatus comprises a casing running downwardly into the well and a tubing string running in the casing. The upper and lower sealing mechanisms are provided for sealing the annular space between the casing and the tubing string, therefore, dividing the well into upper and lower production zones. Moreover, the invention comprises a bypass gaslift system provided with a tubular member, tubing string, connecting means and side pocket mandrels for injecting lifting gas into the multiple production zones well. The system and apparatus according to this invention can selectively operate to simultaneously or separately produce petroleum fluid from vertical apart multiple zones well.

Abstract: Systems and methods usable to operate on a plurality of wells through a single main bore are disclosed herein. One or more chamber junctions are provided in fluid communication with one or more conduits within the single main bore. Each chamber junction includes a first orifice communicating with the surface through the main bore, and one or more additional orifices in fluid communication with individual wells of the plurality of wells. Through the chamber junctions, each of the wells can be individually or simultaneously accessed. A bore selection tool having an upper opening and at least one lower opening can be inserted into the chamber junction such that the one or more lower openings align with orifices in the chamber junction, enabling selected individual or multiple wells to be accessed through the bore selection tool while other wells are isolated from the chamber junction.

Abstract: A set of manifold string members usable to selectively control separate flowing fluid streams of varying velocities for operations of well construction, injection or production of fluid mixtures of liquids, gases and/or solids, that can be injected into, or taken from, one or more proximal regions of a subterranean passageway, underground cavern, hydrocarbon or geothermal reservoir. Fluid communicated through a manifold string radial passageway of a manifold crossover, between conduit strings and at least one other conduit, can be controlled with at least one flow controlling member, communicating with a passageway member from an innermost, concentric, and/or annular passageway. Fluid communication can be selectively controlled for various configurations of one or more substantially hydrocarbon and/or substantially water wells, below a single main bore and wellhead.

Abstract: Assemblies can be disposed in a subterranean bore. An assembly can include a surface that can divert a cutting tool for creating a branch wellbore and that can divert a completion component for completing the branch wellbore without requiring the assembly or part of the assembly from being removed from a parent wellbore prior to the completion component being diverted.

Abstract: Assemblies can be disposed in a subterranean bore. An assembly can include a body and a member that is made from a different material that the material from which the body is made. The member can be located in an opening in the body and can be coupled to the body. The member coupled to the body can define an inner diameter and form a seal for the inner diameter. The member can be milled to access an environment exterior to the member and the body for example to create a branch wellbore.

Abstract: A plurality of zones are gravel packed together and then isolated from each other in the gravel annulus by formation of a barrier in the gravel annulus. The screen assembly carries a series of chambers internally that are located between the producing zones generally in the area of blank pipe between the zones. The wash pipe has a shifter associated with it so that extraction of the wash pipe after gravel packing will serially shift pistons that reduce chamber volume where the chemical is stored. The chemical will exit through a rupture disc and nozzle and will commingle with the gravel and make an impervious annular barrier.

Abstract: A statistical methodology is disclosed to provide time-to-event estimates for oilfield equipment. A method according to the present invention extracts unbiased information from equipment performance data and considers parameters interactions without recourse to data thinning. The analysis explicitly accounts for items of equipment that are still operational at the time of analysis. A method according to the present invention may also be utilized to apply survival analysis to any oilfield equipment components where time-to-event information has been recorded. The method of the present invention allows comparative reckoning between different components present in the system comprising several or many individual components and allows analysis of these components either individually or simultaneously, i.e., in the presence of other components.

Abstract: Selective placement of conformance treatments in multi-zone well completions. A method includes injecting a relative permeability modifier into a zone and optimizing a ratio of desired fluid to undesired fluid produced from the zone, including adjusting at least one flow control device between fully open and fully closed configurations. Another method includes injecting a relative permeability modifier into multiple zones, one at a time, via respective flow control devices, and then producing fluid from each of the zones. Another method includes identifying which of the zones to treat by, for each of the zones: a) closing flow control devices corresponding to the other zones, and b) evaluating fluid produced from the zone; and injecting a conformance treatment into the zones identified as the zones to treat.

Abstract: A method of transmitting power and/or data between downhole equipment and a surface through a circuit including an alternating current (AC) powered motor and its associated power cable for powering the downhole equipment is disclosed, where the data is transmitted at frequencies outside the normal operating ranges that are thought acceptable. Associated circuitry and apparatus for performing the method are disclosed.

Abstract: A property of fluid within a well in a geological volume is controlled. The property of the fluid may include fluid density, pressure gradient, temperature, foaming characteristics, and/or other fluid properties within the well. In particular, the fluid property is controlled discretely within different sections (e.g., at different depths) of the well.

Abstract: The present invention relates to a process for cooling an electrical submersible pump. More specifically, the invention relates to blocking a portion of wellbore fluid from entering a sump, thereby causing the pump to draw fluid from below the pump motor past the exterior of the pump motor toward a pump inlet.

Abstract: A technique includes providing equipment downhole in a well to receive flows. The technique includes regulating a ratio of the flows in the well. The regulation includes regulating the ratio of the flows such that the ratio is substantially independent of pressures of the flows downstream of a point at which the regulation occurs.

Abstract: A tubular valving system includes a tubular having a plurality of ports. A plurality of sleeves are disposed at the tubular covering the plurality of ports, and a plug runnable within the tubular is seatingly engagable with the plurality of sleeves such that attainment of a first pressure applied against the plug and one of the plurality of sleeves causes movement of the one of the plurality of sleeves to thereby uncover at least one of the plurality of ports covered by the one of the plurality of sleeves. At least one of the plurality of sleeves is yieldable to allow passage of the plug upon attainment of a second pressure applied thereagainst, and a plurality of occlusive members occlude the plurality of uncovered ports until a later time.

Abstract: A multilateral access system for a multilateral well including a main well bore and at least one lateral well bore includes a tubular workstring having an inner string and an outer string. The outer string includes a diverter body having a cylindrical housing with a lateral window, the diverter body being shaped and dimensioned to direct the inner string the lateral window and into the at least one lateral well bore. The system is used by positioning the tubular workstring within a multilateral bore. The method further includes positioning the diverter body such that the window of the diverter body faces a milled casing window of the lateral well bore and moving the inner string upwardly above the diverter body. Subsequently, the inner string is lowered back though the diverter body, wherein the diverter body exerts a lateral force on a lower end of the inner string urging the lower end of the inner string toward the milled casing window.

Abstract: Methods and apparatuses for installing lateral wells in an underground. The methods and apparatuses allow for efficiency in a milling and installation process for the lateral well. More specifically, tools and techniques are detailed which allow for controllably guided installation of a whipstock and/or subsequent production deflector hardware at locations adjacent lateral legs of a well to allow for such enhanced milling, installation and production efficiencies.

Abstract: A borehole network including first and second end surface locations and at least one intermediate surface location interconnected by a subterranean path, and a method for connecting a subterranean path between a first borehole including a directional section and a second borehole including a directional section. A directional drilling component is drilled in at least one of the directional sections to obtain a required proximity between the first and second boreholes. An intersecting component is drilled, utilizing magnetic ranging techniques, from one directional section to provide a borehole intersection between the first and second boreholes, thereby connecting the subterranean path.

Abstract: A method of locating a wellbore feature, comprising delivering a mechanical position determination tool into the wellbore, selectively causing an undulating curvature of the mechanical position determination tool in response to a change in a fluid pressure, moving the mechanical position determination tool along a longitudinal length of the wellbore, and sensing a change in resistance to continued movement of the mechanical position determination tool. A mechanical position location tool for a wellbore, comprising pressure actuated elements configured to cooperate to selectively provide an unactuated state in which the mechanical position location tool lies substantially along a longitudinal axis and the pressure actuated elements further configured to cooperate to selectively lie increasingly deviated from the longitudinal axis in response to a change in pressure applied to the mechanical position location tool.

Abstract: A tubing assembly for entering multiple boreholes includes an outer shroud having an axial throughbore, and an inner tubular member disposed in the axial throughbore, wherein the tubular member is releasably coupled to the shroud, and wherein the outer diameter of the shroud is adjustable. A tubing assembly for entering multiple boreholes may also include a shroud having an axial throughbore, a movable tubular member disposed in the axial throughbore, and a releasable coupling between the shroud and the tubular member, wherein the releasable coupling includes a retracted position allowing entry of the tubing assembly into a junction between two boreholes, wherein the releasable coupling includes an expanded position allowing movement of the tubular member relative to the shroud and prevents re-entry of the tubing assembly into the junction.