Directional drilling while conveying a lining member, with latching parking capabilities for multiple trips

A method and system for directional drilling while conveying a liner, with latching parking capabilities for multiple trips, is disclosed. As the wellbore is drilled, each casing and liner is installed having upper and lower interior latch couplings. A liner to be installed below a parent casing includes an exterior latch assembly dimensioned for connection to the interior latch couplings of the parent casing. A bottom hole assembly may include upper and lower exterior inner string latch assemblies for connection to the upper and lower interior latch couplings of the liner to be installed. Such arrangement allows the liner to be conveyed and installed with the bottom hole assembly while directional drilling and for the liner to be temporarily hung from the parent casing for bottom hole assembly change-out while drilling. Float plugs dimensioned to be landed at lower liner interior latch couplings may be provided for cementing operations.

TECHNICAL FIELD

The present disclosure relates generally to oilfield equipment, and in particular to downhole tools, drilling and related systems and techniques for directional drilling and completing wellbores in the earth.

BACKGROUND

From a well construction point of view, the production of oil encounters increased challenges due to formation pressure depletion. Small reservoir pockets may require complex well trajectories with concomitant challenges. Events such as hole instability, loss circulation zones, salt creeping, stuck pipe, etc. may create nonproductive time in the drilling process, and worse, may possibly deny access to intended hydrocarbon reserves entirely. In addition, field development plans may involve more complex well trajectories with narrow mud windows in unstable formations, which may benefit from a different drilling approach to reduce unscheduled events.

DETAILED DESCRIPTION

The present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Further, spatially relative terms, such as “beneath,” “below,” “lower,” “above,” “upper,” “uphole,” “downhole,” “upstream,” “downstream,” and the like, may be used herein for ease of description to describe one element or feature's relationship to another element(s) or feature(s) as illustrated in the Figures. The spatially relative terms are intended to encompass different orientations of the apparatus in use or operation in addition to the orientation depicted in the figures.

FIG. 1is an elevation view in partial cross-section of a liner while drilling system200according to one or more embodiments. A directional drilling while lining system200, as disclosed herein, may allow directional drilling of a wellbore while simultaneously conveying a lining member30. The capabilities of directional drilling system may include, but are not limited to the following: The capability to complete multiple bottom hole assembly trips (for bit or bottom hole assembly replacement, for example); the ability to enlarge the pilot hole; ability for temporary liner hanging; the capability to case the complete open hole; the capability for steering while drilling and rotating; retrievability by a bottom hole assembly; and the ability to perform conventional cementation operations.

As described in greater detail hereinafter, in one or more embodiments, liner while directional drilling system200may be capable of both offshore and onshore use to enable accurate wellbore placement where adverse hole conditions may require casing or liners to be in place. System200may be capable of multiple operations of selective latching and unlatching a lining member30to casing20while handling the weight of the liner and bottom hole assembly and string, withstanding drilling torque requirements, allowing for use in long lateral sections, providing sealing at the top of the liner to the annulus, preserving liner inner diameter, tolerating debris, handling rotation for long periods, providing for fishing operations, and maintaining compatibility with tools and systems presently available. Liner while directional drilling system200may also be capable of conveying and employing float equipment for cementing, including plugs to be activated by dropping balls, bottom plugs to incorporate back pressure valves, and a displacement plug to be latched on top of a bottom plug. Further, liner while directional drilling system200may be drillable.

Moreover, in one or more embodiments, liner while directional drilling system200may include a bottom hole assembly (BHA)210, which may include two reamers to allow total depth reaming of a pilot hole. Such reamers may be wired to a controller in communication with an operator via a downlink telemetry system, for example, by using a surface mud pulser, variation in mud pump operation, rotation of a tubular conveyance, dropping a ball or dart in the mud flow, or activation using a signaling device, such as an radio frequency identification (RFID) device, placed in the mud flow. Such reamers may also be hydraulically activated/deactivated by use of the mud pumps. BHA210may include a wired downhole motor224. Each reamer may be independently actuated or selectively ganged to actuate in unison or in opposite action to each other; for example one reamer may extend its reamer blades while the other reamer may retract its reamer blades.

System200may be located on land, as illustrated, or atop an offshore platform, semi-submersible, drill ship, or any other platform capable of forming wellbore12through one or more downhole formations15. System200may be used in vertical wells, non-vertical or deviated wells, multilateral wells, offshore wells, etc. Wellbore12may include casing20and may include one or more open hole portions.

System200may include a drilling rig144. Drilling rig144may be located generally above a well head167, which in the case of an offshore location is located at the sea bed and may be connected to drilling rig144via a riser (not illustrated). Drilling rig144may include a top drive142, rotary table138, hoist assembly140and other equipment associated with raising, lowering, and rotating a drill string152within wellbore12. Blow out preventers (not expressly shown) and other equipment associated with drilling a wellbore12may also be provided at well head167.

A drill string152may be assembled from individual lengths of casing, drill pipe, coiled tubing, or other tubular goods. In one or more embodiments, drill string152has a hollow interior153. An annulus166is formed between the exterior of drill string152and the inside diameter of wellbore12. The downhole end of drill string152may carry a BHA210. A distal bit214may be a conventional drill bit, reamer, coring bit, or other suitable tool. BHA210may include a motor224, operable to rotate distal bit214. Motor224may be a mud motor. However, an electric motor, powered by a hydraulically-powered electrical generator or electrical connection to the surface, for example, may be used in lieu of a mud motor. In place of a mud motor, a turbodrill vane-type motor or any other type of motoring device may also be used to apply drilling torque to the distal bit214. A tractor assembly or anchoring device157may be provided within BHA210for counteracting any tendency of BHA210to rotate within wellbore12during rotation of distal bit214. BHA210may also include various subs, centralizers, drill collars, logging tools, or similar equipment. Drill string152may carry lining member30, as described in detail hereinafter.

Various types of drilling fluids146may be pumped from pit155through pump148and conduit150to the upper end of drill string152extending from well head167. The drilling fluid146may then flow through longitudinal bore153of drill string152and exit through nozzles (not illustrated) formed in distal bit214or at least a portion of the fluid elsewhere in BHA210or drill string152. Drilling fluid146may mix with formation cuttings and other downhole fluids and debris proximate drill bit214. Drilling fluid146will then flow upwardly through annulus166to return formation cuttings and other downhole debris to well head167. Conduit151may return the drilling fluid to pit155. Various types of screens, filters and/or centrifuges (not expressly shown) may be provided to remove formation cuttings and other downhole debris prior to returning drilling fluid to pit155. Drilling fluid146may also provide a communications channel between BHA210and the surface of wellbore12, via mud pulse telemetry techniques, for example.

FIG. 2is a flow chart of a method100for directional drilling while conveying a liner according to an embodiment. Method100may provide to ability to steer a wellbore to a predefined direction while conveying a liner for casing the newly drilled open hole interval using liner while directional drilling system200. Directional drilling system200may include a steerable BHA210and a vast array of drilling components.

FIG. 3is a an axial cross section of a well10with liner while directional drilling system200according to hole preparation step102ofFIG. 2. Referring toFIGS. 2 and 3, an upper portion14of a wellbore12may be drilled. According to one or more embodiments, the directional lining/drilling process requires advanced planning, as the previous or parent casing or liner member20(hereinafter, simply, parent casing) incorporates internal casing latch couplings22that allow for hanging a directional drilling system-conveyed lining member30(FIG. 5) for the next downhole section during bottom hole assembly changes or once at total depth. Latch couplings22may allow for temporarily parking lining member30for the bottom hole assembly changes or when switching to cementing operations.

Accordingly, at various depths, internal casing latch couplings22may be installed in the previous or parent casing20, depending upon the length and formation drillability of the planned interval. Two or more internal casing latch couplings22a,22bmay be installed on parent casing20, one near the bottom end of parent casing20and the other spaced uphole at least the length of the pilot bottom hole assembly. A third casing latch coupling22cmay be provided for an intermediate drill bit or bottom hole assembly change. Additional casing latch couplings22may also be provided and spaced along parent casing20. Once parent casing20has been run into wellbore12, parent casing20may be conventionally cemented.

FIG. 4is a an axial cross section of well10with liner while directional drilling system200according to hole preparation step104ofFIG. 2. Referring toFIGS. 2 and 4, after cementing parent casing20, a clean-out bottom hole assembly202may be run in order to drill out casing equipment such as the float valves and wiper plug, perform leak off testing (if required), and optionally brush or otherwise clean internal latch couplings22in preparation for liner hanging, if deemed necessary. After the clean-out run, clean-out bottom hole assembly202may be pulled out of hole.

FIG. 5is a an axial cross section of well10with liner while directional drilling system200according to liner running steps106,108,110ofFIG. 2. Referring toFIGS. 2 and 5, after hole preparation, the directional drilling system-conveyed lining member30may be run, as follows:

At step106, lining member30may be provided. Lining member30may include an external liner latch assembly34to allow hanging lining member30from latch couplings22in parent casing20. External liner latch assembly34may complement and allow selective engagement and disengagement with internal casing latch couplings22of parent casing20. External liner latch assembly34may include a housing with multiple latch segments that properly align with and engage slots of predetermined dimensions and orientations in internal casing latch couplings22. In one or more embodiments, latch coupling pairs22,34may employ Halliburton Multilateral Latch System components, which may be installed in the same manner as a standard casing coupler yet provide an anchoring mechanism for accurate and repeatable placement and orientation of equipment. Latch coupling components22,34may be permanently installed in casing20and lining member30, respectively, satisfying burst and collapse pressure requirements while optionally not restricting the inner diameter of the respective string.

In one or more embodiments, the mating latch profile arrangement, such as slots, internal ledges, or internal upsets, may be integrated into the internal portion of the casing or liner tubing itself by direct modification of the liner or casing for the desired anchoring capability of an inner member of the lining that is positioned to latch into the mating latch profile arrangement on the inside of casing or lining member20. Further it is noted that the latch or mating slot arrangements, for example, can be switched to be either on the lining member or on the inner drill string.

The lower end of lining member30may include a liner shoe36that enables conveyance of lining member30. In particular, as with parent casing20, liner internal liner latch couplings32may be provided, with two liner latch couplings32a,32blocated close to the bottom end of lining member30and one liner latch coupling32clocated further uphole, positioned to be below a liner hanger310, as discussed in greater detail hereinafter. The lower two liner latch couplings32a,32bmay accept liner float equipment and plugs for subsequent operations. As with internal casing latch couplings22, internal liner latch couplings32may employ Halliburton Multilateral Latch System components.

At step108, a directional drilling BHA210may be run through lining member30. In one or more embodiments, directional drilling BHA210may include a drill bit214, a total depth or lower reamer216, a rotary steerable system (RSS)218, a measurement while drilling sub220, an upper reamer222, and a motor224. Steering system218may incorporate steerable capabilities to follow a desired trajectory. Measurement while drilling sub220may include a gyro-while-drilling and a telemetry module. The portion of directional drilling BHA210that extends beyond the lower end of lining member30may be minimized by using a wired upper reamer222and a wired motor224and by locating motor224, and at least the telemetry portion of measurement while drilling (MWD) sub220within lining member30but with the output shaft of the mud motor located below the lower latch32aso as to provide drilling torque to the reamers and drill bit. The wiring of the reamer and the mud motor facilitates communication between the portion of the MWD that may remain inside the lining member30and the portion of the BHA210that must remain below the upper reamer222for functional purposes. Such BHA sub systems can include bore hole survey systems, logging while drilling (LWD) systems and portions of the steering assembly that require commands to control such as an actuator in a rotary steerable system.

The position of a borehole survey system that is within the MWD system220may be determined based on the kind of direction sensor it has and whether or not the material in the vicinity of the survey system is magnetizable, such as in the case of ferrous materials like iron and chromium alloys which are common to casing materials. Ferrous materials for example may interfere with a magnetic survey instrument that is used to measure the earth's magnetic field. Thus, such a system may be required to be placed below a ferrous lining member, or at least the portion of lining member. Additionally, other nearby members where the sensor is placed in the lining member would have to be made of a non-magnetic material, such as an austenitic stainless steel, monel, or composite material. As this is an expensive arrangement, a gyroscope may instead be employed in MWD220, which is immune to the effects of magnetizable material in its vicinity and thereby allows the survey portion of the system to be located within the lining member30.

Drilling torque with rotation may also be provided from surface by the drilling rig to assist or in place of the down hole drilling motor in the BHA210by rotating the drill string from surface.

Total depth reamer216may be located just above drill bit214to enlarge the pilot hole at the time the total depth is reached. Conventional reaming technology may involve multiple trips to enlarge the wellbore. Combined with the traditional challenges of downhole steerability, creating an enlarged borehole at total depth may leave the operator with an overlong rat hole. However, total depth reamer216may eliminate the long rat hole with minimal effect on steerability. Total depth reamer216may be a short, integrated reaming tool placed between drill bit214and rotary steerable system218, thus enabling rat hole reduction to as little as three feet and optimizing borehole size at total depth. Elimination of the long rat hole using total depth reamer216may provide an important benefit, as some well plans may require setting lining member30at a specific pressure change point. In one or more embodiments, total depth reamer216may be a Halliburton TDReam™ Tool.

In one or more embodiments, upper reamer222may be a hole enlargement tool engineered to minimize lateral vibrations in simultaneous operations. Excess lateral vibration while simultaneously drilling and reaming may result in a life reduction of rotary steerable system218. Upper reamer222may include a self-stabilizing body and articulated deployment to minimize whirling and side loads transmitted through BHA210during transition drilling operations. Upper reamer222may also provide for reamer deactivation. When finished enlarging the hole, the arms/cutting structure of upper reamer222may be closed and drilling resumed, or upper reamer222may be pulled while simultaneously circulating at full flow rate and rotating. In one or more embodiments, upper reamer222may be a Halliburton XR™ reamer tool.

Directional drilling BHA210may also include a telescoping joint230and upper and lower external inner string latch assemblies232,234for coupling to lining member30. Upper external latch assembly232may be located at or near the top of the directional drilling BHA210to accomplish hanging the string inside lining member30. Upper external latch assembly232may also provide stabilization along the string inside lining member30. Lower external latch assembly234may anchor and transmit torque to lining member30. The exterior surface of lining member30may also include an array of centralizers240. Finally, directional drilling BHA210may include drill pipe242, which may include heavy wall drill pipe, and other components, such as a jar (not illustrated).

At step110, a drilling running tool300may be connected to directional drilling BHA210using liner hanger310. Telescopic joint230may be longitudinally extended to accommodate connection of directional drilling BHA210to drilling running tool300. Additionally, in one or more embodiments, telescopic joint230may be extended by pressurizing the inner string with fluid in order to latch/anchor lower external latch assembly234with a liner latch coupling32.

Liner hanger310may be a flexible liner hanging system, which may include an integral tieback receptacle and expandable solid hanger body311that is bonded to multiple elastomeric elements, and which may provide both a bi-directional annular seal and tensile and compressive load transfer capabilities. A collet assembly312may be connected between directional drilling BHA210and hanger body311to transfer linear forces and torque between liner hanger310and directional drilling BHA210. In an embodiment, liner hanger310may be a Halliburton VersaFlex® liner hanger system.

FIGS. 6 and 7are axial cross sections of well10with liner while directional drilling system200according to well drilling steps112-116ofFIG. 2, in which a lower portion16of wellbore12may be drilled. Referring toFIGS. 2 and 6, at step112, the drilling of a pilot or rat hole18may be performed until upper reamer222is located below the bottom end of parent casing20. Collet assembly312may carry the weight of directional drilling BHA210with lining member30as well as transmit torque to lining member30.

Referring toFIGS. 2 and 7, at step114, upper reamer222may be activated, and directional drilling to total depth, or any intermediate depth, may be continued according to step116, with drill bit214drilling pilot hole18and upper reamer222concurrently enlarging the pilot hole to a desired gauge.

According to decision step118, if directional drilling BHA210requires retrieval at any point prior to reaching total depth, upper reamer222may be deactivated, as annotated in step120ofFIG. 2and illustrated inFIG. 8.

Continuing with step120ofFIG. 2and referring toFIG. 9, lining member30, with directional drilling BHA210, may be moved by drilling running tool300to the nearest interior casing latch coupling22, which may be an upper or the uppermost interior casing latch coupling22c, as illustrated. There, lining member30may be temporarily parked, using the matched exterior liner latch assembly34and parent casing20interior latch coupling22.

Afterwards, as noted in step120ofFIG. 2and illustrated inFIG. 10, directional drilling BHA210may be released from lining member30by disengaging collet assembly312from body311of liner hanger310and by unlatching lower inner string latch assembly234from liner latch coupling32a. Thereafter, according to step120ofFIG. 2and shown inFIG. 11, directional drilling BHA210may be tripped out to the surface using running tool300.

At step122ofFIG. 2, changes to directional drilling BHA210may be made at the surface, as required. Directional drilling BHA210may then be run into wellbore12via running tool300, and collet assembly312of liner hanger310may be engaged with liner hanger body311, as illustrated inFIG. 12. Thereafter, pumping through the inner string may be commenced to extend telescopic joint230to engage/anchor lower latch assembly234with lower liner latch coupling32a. Finally, external liner latch assembly34may be unlatched from casing latching coupling22cto unpark lining member30from casing20.

FIG. 13is a an axial cross section of well10with liner while drilling system200according to directional drilling step124ofFIG. 2. Referring toFIGS. 2 and 13, directional drilling BHA210may be run to the bottom of wellbore12, upper reamer222may be activated, and drilling may be resumed. Until total depth is reached, steps118through124may be repeated as necessary.

When total depth is reached, steps126,128, and130ofFIG. 2may be performed to enlarge pilot hole18and hang lining member30at the lowermost interior casing latch coupling22. In one or more embodiments, running tool300may be used to raise directional drilling BHA210out of pilot hole18, as follows. Referring toFIGS. 2 and 14, upper reamer222may be deactivated. Then, directional drilling BHA210, carrying lining member30, may be pulled by running tool300until total depth reamer216and drill bit214are positioned above pilot hole18. Total depth reamer216may then be activated. Referring toFIG. 15, directional drilling BHA210, with lining member30, may be lowered via running tool300to enlarge pilot hole18to the point where drill bit contacts the bottom of pilot hole12. Total depth reamer216may then be deactivated.

FIG. 16is a an axial cross section of well10with liner while drilling system200illustrating repositioning step128ofFIG. 2. Referring toFIGS. 2 and 16, total depth reamer216is in a deactivated state. Lining member30, with directional drilling BHA210, may be moved by drilling running tool300to the nearest interior casing latch coupling22, which may be an upper or the uppermost interior casing latch coupling22b,22cin casing20. There, lining member30may be temporarily parked, using the matched exterior liner latch assembly34and parent casing20interior latch coupling22. Afterwards, directional drilling BHA210may be released from lining member30by disengaging collet assembly312from body311of liner hanger310and by unlatching lower inner string latch assembly234from liner latch coupling32. Thereafter, directional drilling BHA210may be raised to position and latch upper inner string external latch assembly232at the uppermost interior liner latch coupling32cso that most of directional drilling BHA210is located within lining member30.

As shown inFIG. 17, at step130ofFIG. 2, running tool300may then be lowered to lower lining member30into lower portion16of wellbore12. Lining member30may be manipulated so that exterior liner latch assembly34is positioned and engages lowermost casing latch coupling22a.

However, in one or more embodiments, steps126and128may be performed in a reverse order: Referring toFIGS. 2 and 18, directional drilling BHA210may first be repositioned within lining member30as follows. Upper reamer222may be deactivated. Directional drilling BHA210may be moved by drilling running tool300to align exterior liner latch assembly34with the nearest interior casing latch coupling22, which may be an upper or the uppermost interior casing latch coupling22b,22cin casing20. There, lining member30may be temporarily parked, using the matched exterior liner latch assembly34and parent casing20interior latch coupling22. Afterwards, as shown inFIG. 19, directional drilling BHA210may be released from lining member30by disengaging collet assembly312from body311of liner hanger310and by unlatching lower inner string latch assembly234from liner latch coupling32a. Thereafter, directional drilling BHA210may be raised to position and latch upper inner string external latch assembly232at the uppermost interior liner latch coupling32cso that most of directional drilling BHA210, except for total depth reamer216and drill bit218, is located within lining member30.

Referring toFIG. 20, external liner latch assembly34may next be disengaged from interior casing latch22, and running tool300may be used to raise total depth reamer216out of pilot hole18, if necessary. Total depth reamer216may then be activated. Then, as shown inFIG. 21, directional drilling BHA210, carrying lining member30, may be lowered by running tool300to enlarge pilot hole18to the point where drill bit contacts the bottom of pilot hole12. The inner string upper latch assembly232and liner latch coupling32cwill handle the weight and transmit torque to lining member30.

FIG. 20also illustrates an option that includes a liner shoe reamer217located at the bottom end of lining member30. With drill bit214located in pilot hole18and acting as a guide, lining member30may be rotated by running tool300to rotate liner shoe reamer217to enlarge pilot hole18. Liner shoe reamer217may be used in addition to or in place of total depth reamer216.

As shown inFIG. 22, at the completion of hole enlargement, total depth reamer216may be deactivated. Running tool300may be raised and/or otherwise manipulated to align and connect exterior liner latch assembly34with lowermost casing latch coupling22afor parking lining member30.

Regardless of the order of performance steps126and128ofFIG. 2, at step130, directional drilling BHA210may be unlatched from lining member30by unlatching upper latch assembly232from internal latch coupling32c, and, as illustrated inFIG. 23, running tool and BHA210may be pulled out of hole.

Referring toFIGS. 2 and 24, at unlatching step132an expansion/cementing running tool assembly212having float equipment may be run in hole. Expansion/cementing running tool assembly212may include an expansion tool400, a cement displacement wiper plug402, and upper and lower float plugs410,412. In an embodiment, the profile of the upper and lower float plugs410,412may be such as to be accepted by the liner latch couplings32a,32b. Accordingly, incorporating latch couplings32a,32bat the lower end of lining member30may enhance the ability to perform a conventional liner cementation, as further described below.

Collet assembly312may be engaged with liner hanger body311, and as illustrated inFIG. 25, lining member30may be unlatched from casing20by unlatching exterior liner latch assembly34from interior casing latch coupling22a. Circulation may be provided to remove borehole cuttings and clean wellbore12.

Referring toFIGS. 2 and 26, at step134a cementing operation may be performed as follows. A first drop ball/dart (not illustrated) may be flowed through expansion/cementing running tool assembly212to release lower float plug412, which may land at lower liner latch coupling32a. Similarly, a second drop ball/dart (not illustrated) may be flowed through expansion/cementing running tool assembly212to release upper float plug410, which may land at the next liner latch coupling32b. Dual plugs may serve as redundant back pressure valves and float shoes in a conventional cement process. The shoe track may avoid cement contamination in the annulus. After float plugs410,412have landed at latch couplings32b,32a, respectively, cement430may be pumped through expansion/cementing running tool assembly212.

Next, as shown inFIG. 27, step134(FIG. 2) may continue by dropping a ball/dart (not illustrated) to release cement displacement wiper plug402. Cement pumping may continue, displacing cement displacement wiper plug402downhole until cement displacement wiper plug402bumps and lands atop upper float valve410.

Referring toFIGS. 2 and 28, at expansion step136, liner hanger310, which in an embodiment may be a Halliburton VersaFlex® liner hanger, may be expanded hydraulically by dropping a ball, using expansion tool400. Collet assembly312may then be disengaged and lifted. Circulation to clean wellbore12may be performed, and expansion tool400may be pulled out of hole using running tool300.

In summary, a method for forming a wellbore and a liner running system have been described. Embodiments of the method for forming a wellbore may generally include: installing a casing in an upper portion of a wellbore, the casing having upper and lower interior casing latch coupling; providing a bottom hole assembly having upper and lower exterior inner string latch assemblies; disposing the bottom hole assembly through a lining member, the lining member having a upper and lower interior liner latch couplings each dimensioned for connection to the upper and lower exterior inner string latch assemblies and an exterior liner latch assembly dimensioned for connection to the upper and lower interior casing latch couplings; connecting the bottom hole assembly to a running tool; connecting the exterior inner string latch assembly to the lower interior liner latch coupling, with at least a lower portion of the bottom hole assembly extending beyond a lower edge of the lining member; and lowering the bottom hole assembly with the lining member into the casing by the running tool. Embodiments of the liner running system may generally have: a bottom hole assembly having upper and lower exterior inner string latch assemblies; and a lining member having a upper and lower interior liner latch couplings each dimensioned for connection to the upper and lower exterior inner string latch assemblies and an exterior liner latch assembly dimensioned for connection to upper and lower interior casing latch couplings; whereby the bottom hole assembly is adapted to selectively carry the lining member via the exterior inner string latch assembly and the lower interior liner latch coupling.

Any of the foregoing embodiments may include any one of the following elements or characteristics, alone or in combination with each other: the bottom hole assembly is a directional drilling bottom hole assembly; directionally drilling a lower portion of the wellbore along a well trajectory using a drill bit and a steerable system of the directional drilling bottom hole assembly; the lower portion of the bottom hole assembly extending beyond the lower edge of the lining member includes a reamer; drilling a pilot hole of lower portion of the wellbore using the drill bit; reaming the pilot hole below the casing using the reamer; hanging the lining member by the exterior liner latch assembly from one of the upper and lower interior casing latch couplings; disconnecting the lower exterior inner string latch assembly from the lower interior liner latch coupling; removing the bottom hole assembly from the wellbore; reinserting the bottom hole assembly into the wellbore; connecting the lower exterior inner string latch assembly to the lower interior liner latch coupling; disconnecting the exterior liner latch assembly from the one of the upper and lower interior casing latch coupling; reaming a pilot hole to a near total depth by a total depth reamer of the bottom hole assembly; raising the bottom hole assembly and the lining member; hanging the lining member by the exterior liner latch assembly from the upper interior casing latch coupling; disconnecting the lower exterior inner string latch assembly from the lower interior liner latch coupling; raising the bottom hole assembly within the lining member; connecting the one of the upper and lower exterior inner string latch assemblies to the upper interior liner latch coupling so that a substantial portion of the bottom hole assembly is disposed within the lining member; lowering the bottom hole assembly and the lining member; hanging the lining member by the exterior liner latch assembly from the lower interior casing latch coupling; disconnecting the lower exterior inner string latch assembly from the upper interior liner latch coupling; removing the bottom hole assembly from the wellbore; providing a liner hanger having a hanger body and a collet assembly, the hanger body connected to the lining member, the collet assembly connected between the bottom hole assembly and the running tool; transmitting torque and axial force by the collet assembly between the running tool and the bottom hole assembly; providing a telescopic joint within the bottom hole assembly; selectively engaging the collet assembly with the hanger body; selectively extending the telescopic joint to connect the exterior inner string latch assembly to the lower interior liner latch coupling; the bottom hole assembly is an expansion/cementing running tool assembly having an expansion tool, and displacement wiper plug, and a float plug; engaging the collet assembly to the hanger body, flowing a first drop ball/dart through the expansion/cementing running tool assembly to release the float plug; landing the float plug at the lower interior liner latch coupling; pumping cement through the expansion/cementing running tool into the wellbore; flowing a second drop ball/dart through the expansion/cementing running tool assembly to release the wiper plug; displacing the wiper plug downhole until the wiper plug lands on the float plug; expanding the expansion tool; disengaging the collet assembly from the hanger body; removing the collet assembly from the wellbore by the running tool; the bottom hole assembly is a clean-out bottom hole assembly; cleaning the wellbore with the clean-out bottom hole assembly; the bottom hole assembly is a steerable directional drilling bottom hole assembly including a drill bit, a reamer, a motor, and a measurement while drilling sub; the bottom hole assembly includes a total depth reamer disposed adjacent the drill bit; the motor and the measurement while drilling sub are selectively disposed within the lining member; a liner hanger having a hanger body and a collet assembly, the hanger body connected to the lining member, the collet assembly connected between the bottom hole assembly and the running tool; a telescopic joint disposed within the bottom hole assembly between the collet assembly and the lower exterior inner string latch assembly; the bottom hole assembly is an expansion/cementing running tool assembly having an expansion tool, and displacement wiper plug, and a float plug, the float plug dimensioned for connection to the lower exterior inner string latch assembly; first and second lower interior liner latch couplings located within the interior of the lining member; first and second float plugs dimensioned for connection to the first and second lower exterior inner string latch assemblies, respectively; and the bottom hole assembly is a clean-out bottom hole assembly.

The Abstract of the disclosure is solely for providing the a way by which to determine quickly from a cursory reading the nature and gist of technical disclosure, and it represents solely one or more embodiments.

While various embodiments have been illustrated in detail, the disclosure is not limited to the embodiments shown. Modifications and adaptations of the above embodiments may occur to those skilled in the art. Such modifications and adaptations are in the spirit and scope of the disclosure.