Abstract: A system and method for accessing a well, in certain embodiments, includes a production tree, a cap, and a spool including a longitudinal bore configured to receive a tubing hanger. The tubing hanger includes a longitudinal bore configured to transfer product between the spool and the production tree. At least one adjustable fluid barrier is included in the tubing hanger and/or the cap. The adjustable fluid barrier can be used to open and close the longitudinal passage and allow access through the tubing hanger and/or the cap.

Abstract: A technique facilitates active zonal control over the inflow of fluids into a lateral wellbore completion at individual well zones of a plurality of well zones. The completion may comprise a plurality of sand screens through which inflowing fluids pass before entering an interior of the completion, e.g. before entering an interior of a completion base pipe. A control module is positioned along the completion between well zones. The control module is controlled via electrical control signals and is operatively connected with a plurality of intelligent flow control devices which are located along the completion in corresponding well zones. Based on signals received, the control module individually controls the intelligent flow control devices to allow or block flow into an interior of the completion at each well zone.

Abstract: A method of completing a wellbore system that includes a main wellbore and a lateral wellbore intersecting the main wellbore at a junction is disclosed, wherein in one embodiment the method includes placing a first outer assembly below the junction in the main wellbore and placing a second outer assembly below the junction in the lateral wellbore; placing a first inner assembly in the second outer assembly with a top end thereof below the junction, the top end of the first inner assembly including a first wet connect associated with at least one link in the first inner assembly; and connecting a second wet connect of a string with the first wet connect with a top end of the string having a third wet connect corresponding to the at least one link above the junction in the main wellbore.

Abstract: A first sleeve is shifted with a ball landed on a seat to open treating ports. At the conclusion of the treating such as fracturing, another ball is dropped on a seat in an adjacent sleeve. The adjacent sleeve shifts to contact the initial sleeve that was shifted earlier. When the sleeves abut the treating ports are closed by the second sleeve and the production ports that are preferably screened are also opened by the shifting of the second sleeve against the first sleeve. The first sleeve hits a travel stop in the housing to produce the full open position for the treating ports. The balls can be progressively larger in a bottom up direction for the procedure or the balls can all be the same size as the landing of a ball on the first sleeve reconfigures the sleeve above for the same sized ball.

Abstract: A wellbore lining system that puts liners into place immediately behind the drill head tool is used in drilling and for preparing natural gas hydrate (NGH) deposits for production of its natural gas. The system overcomes the requirement of setting casing from the wellhead, which controls well bore diameter with depth and allows for flexibility in well bore size at any depth. Wellbore liners stabilize the well walls by being very tightly fitting against bounding rocks and sediments, which overcomes the requirement for cementing, which commonly accompanies conventional well casing. In addition, liners can be emplaced with designed impermeability, permeability, and complex flow-through patterns so that production processes, such as sand flow, can be put in place as part of a liner section.

Abstract: One aspect relates to a method of installing a transmission system in a hydrocarbon production well. The transmission system is operable for transmitting power and/or control signals down the well or for transmitting data signals back up the well. The well comprises a main well bore, a production tubing inside the main well bore and a branch off the production tubing. The branch comprises a side track tubing. The method includes: providing a sensor and/or load assembly in the branch; installing a first inductive coupler of an induced current transmission arrangement around the production tubing in the main well bore, and connecting the sensor/load assembly to the first inductive coupler via a communication link. Another aspect relates to a hydrocarbon production well installation.

Abstract: An intelligent dart or ball or other shape is dropped or pumped into a borehole that has multiple valves for access to the formation through which fractures are initiated. The intelligent object engages with the valves as it passes with retractable engagement dogs that are outwardly biased but not to the degree needed to find support unless the valve in question is the one that needs to be operated. In that event the dogs become supported and pressure is applied to the object to shift the valve to the open position. The object can be released at a later time remotely or can be milled out. Subsequent objects can be landed in the same sleeve after the initial object is released to close it or to close the open port by moving a second sleeve against a first sleeve. Fracturing in any order is envisioned.

Abstract: An obturator for actuating a downhole tool having a central bore. The obturator comprising a body of a size and shape to pass through the central bore of the tool and an engagement member releasably attached to the exterior of the tool body, the engagement member being of a size and shape to engage and actuate the tool.

Abstract: An example multi-bore junction assembly includes a connector body having an upper end and a lower end, the lower end providing a main bore leg receptacle and a lateral bore leg receptacle, a main bore leg coupled to the main bore leg receptacle and extending longitudinally therefrom, a lateral bore leg coupled to the lateral bore leg receptacle and extending longitudinally therefrom, wherein the main and lateral bore legs are round, tubular structures, and a first mechanical stiffener arranged on the main bore leg and a second mechanical stiffener arranged on the lateral bore leg, wherein the first and second mechanical stiffeners each exhibit a generally D-shaped cross-section.

Abstract: A method of deploying a multi-zone completion assembly in a wellbore is disclosed. The method includes: placing an outer assembly below a surface location, wherein the outer assembly includes an activation device. The method further includes placing an inner assembly in the outer assembly, the inner assembly including a lower opening tool spaced from an upper opening tool. The method further includes activating the lower opening tool using the activation device The method further includes activating the upper opening tool independent of the lower opening tool using the activation device.

Abstract: A method of completing a wellbore involves placing a series of sliding sleeves along a string of production casing in the wellbore and includes dropping a frac ball into the wellbore and landing it on a seat associated with an uppermost sleeve. Pressure is applied to activate the sleeve, open ports along the casing, and fracture a surrounding subsurface formation at a selected zone. Ball sealers are pumped down the well and seated within the sleeve ports. Additional fluid pressure is applied to cause the sleeve to shift further down the well and to release the ball, whereupon the frac ball is pumped to a next lower sleeve. This process may be repeated for multiple sleeves at multiple zones for top-down, multi-stage perforations. A novel sliding sleeve that permits a single ball to be used for activating multiple of the sleeves in series, from heel-to-toe, is also offered.

Abstract: A wellhead assembly including a tubing hanger adapted to be connected to a tubing string and landed in a wellhead, and defining a tubing annulus between the tubing string and casing in a well. The wellhead assembly also includes a tubing annulus upper access bore extending downward from an upper end of the tubing hanger, and a tubing annulus lower access bore extending upward from a lower end of the tubing hanger and misaligned with the upper access bore, the lower access bore adapted to communicated with the tubing annulus. A communication cavity connects the upper and lower access bores within the tubing hanger. A remotely actuated valve is in the communication cavity for selectively opening and closing communication between the lower access bore and the upper access bore.

Abstract: An apparatus for use in a wellbore contains a flow control device for use in a wellbore that includes a bore that provides a first flow path and a second flow path via an annulus around the first flow path. The apparatus further includes a closing device that closes the second flow path when the closing device is mechanically moved in a first direction and an opening device that opens the second flow path when a fluid under pressure is supplied to the annulus when a valve is closed.

Abstract: An example tubing string may at least partially define an internal bore. The tubing string may include an expandable packer and a permeable barrier. The tubing string may further include a remotely-controllable valve responsive to at least one downhole trigger condition, such as a downhole pressure or temperature condition. The remotely-controllable valve may provide selective fluid communication through the permeable barrier between the internal bore and an annulus outside of the permeable barrier. The remotely-controllable valve may function as at least one of a fluid-loss control valve in a completion string assembly or a circulation valve about a completion string assembly.

Abstract: Methods and systems monitor conditions in a hydrocarbon reservoir with a multilateral observation well. The observation well may detect vertical development of a steam chamber that forms in the reservoir during thermal hydrocarbon recovery operations. Further, the observation well may include branches that extend to form vertical bores with temperature sensors for the monitoring, which may occur during the recovery operations performed in other wells since the observation well may be dedicated to only the monitoring.

Abstract: The invention relates to a device for determining the depth and orientation of a feature in a wellbore, and to a corresponding method. It also relates to a downhole apparatus for performing an operation in a well comprising a device for determining the depth and orientation of a feature in a wellbore and a device for performing the operation. In an embodiment, a downhole device (42) for determining the depth and orientation of a feature (24, 26, 28) in a wellbore (12) containing a ferrous tubing (14) is disclosed, the device comprising: at least one magnetic field sensor (44) for monitoring the inherent magnetic field of the ferrous tubing so that the presence of the feature can be detected; and at least one orientation sensor (48) for determining the orientation of the device within the wellbore.

Abstract: A technique facilitates selectively disengaging a running string from a lateral tube assembly. The running string comprises a running sub which is engageable with the lateral tube assembly. The running string further comprises a window finder which is positioned to extend into a main bore casing window when the running string is deployed downhole with the lateral tube assembly. Additionally, the running string comprises an extension sub which is coupled to the window finder. The extension sub is selectively extensible to disengage the window finder from the main bore casing prior to release of the running sub from the lateral tube assembly via a release force applied through the running string.

Abstract: A subsea hydrocarbon production system comprises a tubing hanger which is positioned at an upper end of a well bore, a tubing string which extends from the tubing hanger into the well bore and is fluidly connected to the tubing hanger production bore, and a christmas tree which is positioned above the tubing hanger. The christmas tree comprises a production bore which is fluidly connected to the tubing hanger production bore, a production outlet which is connected to the production bore, a first barrier element which is positioned in the production outlet, and a first closure device which is positioned in the production bore above the production outlet. In this manner access from above the christmas tree through the production bore does not require passage through a barrier element.

Abstract: A system and method for downhole data communication using an infrasound wave generator and receivers. The infrasound waves have a low frequency and a wavelength that is much larger than the transverse dimensions of the well. When the infrasound waves are directed down the well, the well will act as a wave guide for low frequency excitations. The receivers are operatively connected to inflow valves and other downhole equipment, and receive the infrasound waves. If the waves are of a predetermined frequency, the receivers command the valves to open or close, or otherwise control downhole equipment. The infrasound waves can also be used to probe well geometry and to identify fluid properties within the well.

Abstract: A system and method is provided for setting a metal-to-metal seal (e.g., in an annular space between wellhead components) using a temporary elastomer seal. For example, the annular space may be sealed with one or more elastomer seals before hydraulically setting the metal-to-metal seal. A seal assembly may include the elastomer seals and the metal-to-metal seal. Positioning the seal assembly in the annular space between the wellhead components may isolate pressure in the annular space below the seal such that the metal-to-metal seal may be set. In an exemplary embodiment, a hydraulic mechanism axially compresses the metal-to-metal seal between two members of the seal assembly, thereby radially expanding and setting the metal-to-metal seal.

Abstract: A wearable computing device such as a head-mounted display (HMD) may be equipped with a magnetometer for detecting presence and motion of a hand-wearable magnet (HWM). The HMD may analyze magnetic field measurements of the magnetometer to determine when the HWM moves within a threshold distance of the magnetometer, and may thereafter determine one or more patterns of motion of the HWM based the magnetic field measurements. The HMD may operate in a background detection state in order to determine a background magnetic field strength and to monitor for magnetic disturbances from the HWM. Upon occurrence of a trigger event corresponding to magnetic disturbance above a threshold level, the HMD may transition to operating in a gesture detection state in which it analyzes magnetometer measurements for correspondence with known gestures. Upon recognizing a known gesture, the HMD may carry out one or more actions based on the recognized known gesture.

Abstract: A well system includes a deflector arranged within a main bore of a wellbore and defining a first channel that exhibits a predetermined diameter and communicates with a lower portion of the main bore, and a second channel that communicates with a lateral bore. A bullnose assembly has a bullnose tip, a piston movably arranged within the bullnose tip, and a wedge member operatively coupled to the piston such that movement of the piston correspondingly moves the wedge member. A coil is arranged about the bullnose tip and in contact with the wedge member, and the piston is actuatable to move the wedge member and thereby radially expand the coil. When the coil is radially expanded, the diameter of the bullnose tip exceeds the predetermined diameter.

Abstract: A technique facilitates selectively disengaging a running string from a lateral tube assembly. The running string comprises a running sub which is engageable with the lateral tube assembly. The running string further comprises a window finder which is positioned to extend into a main bore casing window when the running string is deployed downhole with the lateral tube assembly. Additionally, the running string comprises an extension sub which is coupled to the window finder. The extension sub is selectively extensible to disengage the window finder from the main bore casing prior to release of the running sub from the lateral tube assembly via a release force applied through the running string.

Abstract: Disclosed are expandable bullnose assemblies. One bullnose assembly includes a body and a bullnose tip arranged at a distal end of the body, a compression ring arranged about an exterior of the body and configured to axially translate with respect to the body upon being actuated, and a plurality of collet fingers coupled to and extending between the compression ring and the bullnose tip, each collet finger being pre-compressed such that each collet finger is predisposed to bow radially outwards, wherein, when the compression ring is actuated, the plurality of collet fingers move radially outward from a first diameter to a second diameter that is greater than the first diameter.

Abstract: A wellhead system for supporting at least one section of a casing in a borehole for use with a conductor pipe and a method for installing a wellhead system upon a conductor pipe are disclosed. The wellhead system may include a wellhead housing having a central interior bore with a diameter that is smaller than the interior diameter of the conductor pipe and a blowout preventer having an interior bore having a diameter which is less than the diameter of the conductor pipe. The method may include securing a wellhead housing having a central interior bore with a diameter that is smaller than the interior diameter of the conductor pipe and associating with the wellhead housing a blowout preventer having a central interior bore with a diameter that is smaller than the interior diameter of the conductor pipe.

Abstract: A system and methodology facilitates use of a diverter latch assembly in cooperation with a lateral wellbore. The diverter latch assembly comprises an upper latch assembly coupled with a lower latch assembly via a swivel. The upper latch assembly also comprises a releasable latch positioned to engage a tieback receptacle located in the well. The swivel and the releasable latch are designed to enable rotation of the releasable latch relative to a tubing of the lower latch assembly during release of the diverter latch assembly from the tieback receptacle. The rotational release system helps provide controlled release and withdrawal of the diverter latch assembly while reducing risk of damage to the diverter latch assembly or other downhole components.

Abstract: A method for producing hydrocarbons in a subterranean well useful for observing properties of one or more subterranean zones, includes the steps of: (a) installing a lower straddle packer in a vertical well section below a junction with a lateral well section; (b) installing an upper straddle packer in a vertical well section above the junction with the lateral well section; (c) conveying hydrocarbons from the lateral well section to the surface with a tubing; (d) observing pressure information in at least one zone with a pressure gauge located in the vertical well section below the lower straddle packer; and (e) obtaining information in the at least one zone with logging equipment run through the tubing. A sidetrack window may be installed in the tubing between the lower straddle packer and the upper straddle packer for providing access to the lateral well section.

Abstract: A method for constructing a multilateral well includes drilling a main well, drilling a first lateral well from the main well, installing a production reentry deflection tool in the main well, proximate the first lateral, the first production reentry deflection tool having a first inner diameter, drilling a second lateral well from the main well and above the first lateral well, and installing a second production reentry deflection tool in the main well, proximate the second lateral, the second production reentry deflection tool having a second inner diameter. The first inner diameter is smaller than the second inner diameter.

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: A method of preventing fluid flow past a tapered face of a mill diverter in a wellbore comprises: positioning the mill diverter in the wellbore, wherein the mill diverter comprises: a body; the tapered face, wherein the tapered face is located at one end of the body; and a swellable material, wherein the swellable material: is positioned circumferentially around the body of the mill diverter adjacent to the tapered face; swells in the presence of a swelling fluid; and prevents substantially all of a fluid from flowing past the swellable material after the swellable material has swelled; and causing or allowing the swellable material to swell. The swellable material can also prevent a loss of pressure in the wellbore above the swellable material or prevent a first fluid having a first density from mixing with a second fluid having a second density after the swellable material has swelled.

Abstract: A submersible well pump assembly include a rotary pump driven by an electrical motor. A seal section operably connects between the motor and the pump for reducing a pressure differential between motor oil in the motor and well fluid surrounding the pump assembly. The pump assembly contains a sealed fluid. A sensor mounted to the well pump assembly detects contamination of the sealed fluid by well fluid encroaching into contact with the sealed fluid. The sensor may be mounted in the motor or the seal section to detect well fluid contamination of motor oil. The sensor may be mounted in a secondary pump that has that has temporary barriers to block the entry of well fluid into a buffer fluid contained in the secondary pump while the secondary pump is in a storage condition within a well.

Abstract: An apparatus includes a string that extends into a well and a tool that is disposed in the string. The tool is adapted to form a seat to catch an object communicated to the tool via a passageway of the string in response to the tool being perforated.

Abstract: The present invention relates to drilling lateral wells or sidetrack wells from a primary wellbore to enhance the efficiency and productivity of oil and gas wells.

Abstract: An internal completion string is anchored within a closed casing valve of a production liner in a wellbore. The internal completion string comprises a packer and a shifting tool. The production liner comprises a casing valve having a port and a moveable member. The annulus defined between the production liner and the internal completion string is sealed, and the shifting tool is remotely operated to move the moveable member away from the port, thereby opening the casing valve.

Abstract: A method of deploying a tool in a wellbore includes installing a tool body at an upper end of a tubular string extending from a wellbore, the body having at least one control line groove formed on its outer surface with the at least one control line housed therein. The method also includes providing an assembly strung on the at least one control line. The assembly includes an element with at least one ring on each end thereof; at least one ring on each end of the element; a locking ring at an upper end of the assembly. The method further includes installing the assembly over the body to house the at least one control line between the body and the assembly.

Abstract: Disclosed is a method and apparatus for completing an injection well, wherein the horizontally-extending portion of the well is drilled in a wave pattern. Injection and hydrocarbon recovery sections or alternatively spaced along the horizontally-extending portion and are isolated from each other by packers in the wellbore. The injection and hydrocarbon recovery sections are positioned at the opposed peaks of the wave pattern.

Abstract: A wellbore system includes an upper deflector arranged within a main bore of a wellbore and defines first and second channels. A lower deflector is arranged within the main bore and spaced from the upper deflector by a predetermined distance and defines a first conduit exhibiting a predetermined diameter and communicating with a lower portion of the main bore and a second conduit that communicates with a lateral bore. A bullnose assembly includes a body and a bullnose tip arranged at a distal end of the body, the bullnose assembly being actuatable between a default configuration and an actuated configuration. The upper and lower deflectors direct the bullnose assembly into one of the lateral bore and the lower portion of the main bore based on a length and a diameter of the bullnose tip as compared to the predetermined distance and the predetermined diameter, respectively.

Abstract: First equipment is provided in a first lateral branch of a well, and second equipment in a second lateral branch of the well. Cross-lateral logging is performed using the first and second equipment in the corresponding first and second lateral branches.

Abstract: A multi-deflector assembly for guiding a bullnose assembly into a selected borehole within a wellbore includes an upper deflector arranged within a main bore of a wellbore and defining first and second channels that extend longitudinally through the upper deflector, wherein the second channel exhibits a width greater than that of the first channel. A lower deflector is arranged within the main bore and spaced from the upper deflector by a predetermined distance. The lower deflector defines a first conduit that communicates with a lower portion of the main bore and a second conduit that communicates with a lateral bore. The upper and lower deflectors are configured to direct a bullnose assembly into one of the lateral bore and the lower portion of the main bore based on a length of a bullnose tip of the bullnose assembly as compared to the predetermined distance.

Abstract: Disclosed are systems and methods for providing a casing exit. One method includes introducing into a wellbore a casing section having an outer sleeve and an inner sleeve rotatably received within the outer sleeve, the outer sleeve defining an outer window and the inner sleeve defining an inner window rotationally alignable with the outer window, wherein the inner sleeve defines a first alignment portion engageable to rotate the inner sleeve, advancing the casing section to a wellbore location with the inner window rotationally misaligned with the outer window, extending a deflector tool within the casing section such that a second alignment portion provided on the deflector tool engages the first alignment portion, and rotating the deflector tool such that the inner sleeve rotates with respect to the outer sleeve and moves the casing section into an open configuration where the inner window is rotationally aligned with the outer window.

Abstract: A sampling system and a method for sampling fluid from a target zone within a well bore without commingling fluid from other zones in the well. The sampling system includes a hydraulic flow control system and a differential flow logging system. The hydraulic flow control system has a plurality of multi-level, vertically disposed pumps with fluid extraction rates set to generate hydraulic zones above and below a center one of the pumps. The hydraulic zones isolate fluid flow in a target zone surrounding the center pump, and the center pump collects a sample from the isolated target zone without mixing fluid from other zones of the well. The differential logging system has a plurality of flow devices. Each of the plurality of flow devices is disposed near one of the hydraulic zones to monitor vertical flow in the well and confirm isolation of the target zone.

Abstract: A system for circumferentially aligning a downhole latch subsystem in a wellbore. The system includes an outer tool assembly including a latch coupling having a latch profile and a slot subassembly having an axially extending slot profile. An inner tool assembly is positionable within the outer tool assembly. The inner tool assembly includes a latch assembly having a plurality of latch keys and an orienting subassembly having a plurality orienting keys. In operation, after axial alignment of the orienting subassembly with the slot subassembly, rotation of the orienting subassembly causes operable engagement of at least one orienting key with the slot profile and, thereafter, axial alignment of the latch assembly with the latch coupling causes operable engagement of the latch keys with the latch profile.

Abstract: A downhole latch assembly has a plurality of latch keys including a primary latch key. A window joint is interconnected in a casing string positioned in a wellbore. A latch coupling having a latch profile is interconnected in the casing string downhole of the window joint. An orienting subassembly interconnected in the casing string has an orienting profile positioned uphole of the latch profile such that after operable engagement of the primary latch key with the orienting profile, axial alignment of the latch assembly with the latch coupling causes operable engagement of the latch keys with the latch profile.

Abstract: A method and apparatus for extracting geothermal energy from a subterranean thermal reservoir through a wellbore where the heat exchange fluid is introduced at a slower velocity than the velocity at which the fluid is extracted. The method and apparatus further comprises a gas zone near the top of the wellbore to maintain the thermal energy of the heat exchange fluid. In one embodiment, a portion of the casing of the wellbore can directly contact the subterranean environment. Alternatively, a thermally conductive wall comprising a thermally conductive material can surround a portion of the casing of the wellbore. Further, the inner and/or outer surface of the pipes and conduits of the disclosed method and apparatus can include modified surface features that influence the flow and/or thermal conductivity of the heat exchange fluid.

Abstract: Disclosed are systems and methods of producing from multiple production zones with a single trip multi-zone completion system. One method includes arranging an outer completion string within a wellbore adjacent the one or more formation zones, the outer completion string having at least one sand screen arranged thereabout and a flow control device movably disposed within the sand screen, locating an insert string within the outer completion string, the insert string having at least one control and data acquisition module disposed thereon that has one or more mechanical coupling mechanisms, locating the flow control device with the one or more mechanical coupling mechanisms, and moving the flow control device between a closed position and an open position with the one or more mechanical coupling mechanisms.

Abstract: A multilateral junction system includes a multilateral junction device including a first bore leg; a second bore leg; a joint section having a first opening connected to the first bore leg and a second opening connected to the second bore leg. A main body extending from the joint section and including a third opening; and, a tube connected to the third opening. The tube configured to enable an upper completion to be run into a borehole together with the multilateral junction device. Also included is a method of improving multilateral operations in a borehole.

Abstract: A subassembly is provided which is designed so that two passageways in concentrically arranged tubing strings can be formed to provide a flow-path which in a first direction communicates with equipment at surface in an annular passageway then switches partway along the tubing strings' length in the well to the subassembly and is redirected to the core passageway, and back from the string's lower end up the annular space to the subassembly and is again redirected this time to the tubing's core passageway back to surface equipment; the two passageways being: the core passageway formed of the core tubing's inner volume; and the annular passageway formed of the annular space between the core tubing string and a concentrically surrounding second tubing string's inner surface; the subassembly forming a two-way cross-over between the two passageways at the same part of the string.

Abstract: The lowside of a casing joint is protected from wear while milling a casing exit for a lateral borehole. The casing joint is coupled to a casing string and is made of a material that is softer than that of the casing string. A whipstock assembly is arranged within the casing joint and has a deflector surface operable to direct a drilling assembly into a sidewall of the casing joint to create the casing exit. A wear sleeve is coupled to and extends axially from the whipstock assembly, the wear sleeve defining a throat that extends axially along the axial length of the wear sleeve and transitions into the deflector surface. The axial length of the wear sleeve extends beyond a point of contact where the drilling assembly would otherwise engage the lowside of the casing joint.

Abstract: A system for removing liquids from an inclined wellbore includes a plug member positioned within a heel section of the inclined wellbore, the plug member including an orifice therethrough; a first tubular member having a first end for providing fluid flow from the first portion of the wellbore to the second portion of the wellbore, a second end positioned at least partially within the second portion of the wellbore and providing fluid flow from the first portion of the wellbore to the second portion of the wellbore; a second tubular member positioned within the second portion of the wellbore, the second tubular member having a first end for receiving fluid from the second portion of the wellbore, the second end positioned adjacent the surface of the inclined wellbore; and a pump for pumping fluid from the second tubular member to the surface.

Abstract: A system for producing hydrocarbons from a subterranean well including a wellbore extending from a surface into a subterranean formation, the system including a wellhead disposed at the surface. In addition, the system includes a production tree coupled to the wellhead. Further, the system includes a casing coupled to the wellhead and extending into the wellbore. Still further, the system includes a first plurality of production tubing strings extending into the casing from the wellhead to a first production zone. Each of the first plurality of production tubing strings is configured to provide a fluid flow path for gases from the first production zone. The production tree is configured to selectively and independently control fluid flow through each of the first plurality of production tubing strings.