Patent Description:
Drilling fluid loss mitigation and consequence can be temporally and economically inefficient. When unacceptable drilling fluid losses are encountered, conventional lost circulation technologies can be deployed into the drilling fluid from a terranean surface. The drilling fluid, which includes loss mitigation chemicals, can be pumped downhole as part of the standard well circulation system. The modified drilling fluid passes through a bottom hole assembly (BHA), including a drill bit, or bypasses the BHA through a circulation port and can be designed to plug (for example, pressure seal) the exposed formation at a location in the wellbore in which losses are occurring. Once sealing of the wellbore has occurred and acceptable fluid loss control is established, drilling operations may resume. Conventional lost circulation material (LCM) may seal uniformly shaped formation voids (for example, widths) up to approximately <NUM>-<NUM> millimeters (mm) but struggle with un-uniform and larger voids. Effective sealing is often both challenging and costly. In addition to replacing costly drilling fluid, drilling operations may need to cease in order to take time resolving the fluid losses before continuing to drill into a subterranean zone. Such measures may include pumping increasingly coarse grades of LCM, junk plugs, attempting to cement over the loss point or running casing to place the loss-inducing formation behind steel and squeezing a cement isolating barrier.

<CIT> describes remediation or a lost circulation zone in a wellbore. A flexible liner is deployed adjacent the lost circulation zone that blocks fluid communication between the wellbore and surrounding formation. The liner material has a designated yield and tensile strength, so that in response to pressure applied in the wellbore the liner flexes and conforms to contours in the wellbore. The liner remains intact during deformation to maintain the flow barrier between the wellbore and formation. The liner is set in the wellbore with a bottom hole assembly that includes an outer housing for protecting the liner during the trip downhole.

<CIT> describes an apparatus and method for setting a cementitious material plug in an irregularly shaped and/or over gauge well bore without contamination of the cementitious material by extruding a membrane filled with cementitious material from a membrane delivery device.

<CIT> describes a downhole liner delivery tool includes a housing configured to couple to a tubular work string. The housing includes an interior volume. The tool also includes a liner store enclosed within the interior volume. The liner store is configured to enclose at least a portion of a wellbore liner that includes a flexible membrane. The flexible membrane includes an imbedded epoxy. The tool also includes a hydraulic circulation system arranged in at least a portion of the interior volume and configured to circulate a fluid to expand the wellbore liner from the liner store to an exterior of the housing to contactingly engage a wellbore wall.

<CIT> describes an apparatus for setting a plug in a borehole.

In an example implementation, a downhole liner delivery tool is defined in claim <NUM>.

An aspect combinable with the example implementation further includes a flow crossover sub-assembly positioned in the housing and including one or more ports fluidly coupled to the wellbore through the housing in a first position of the flow crossover sub-assembly to circulate the fluid resin from the flow path to the wellbore.

In another aspect combinable with any of the previous aspects, the flow crossover sub-assembly is configured to move from the first position to a second position based on breaking one or more shear pins that couples the flow crossover sub-assembly to the housing by the fluid pressure to fluidly decouple the one or more ports from the wellbore to circulate the fluid resin to anchor the one or more retractable grips to the wellbore wall.

In another aspect combinable with any of the previous aspects, the housing includes an index pin positioned to ride in a groove formed on an outer surface of the flow crossover sub-assembly during movement of the flow crossover sub-assembly from the first position to the second position.

In another aspect combinable with any of the previous aspects, the groove includes a slot formed to stop movement of the flow crossover sub-assembly at the second position and maintain the flow crossover sub-assembly at the second position.

Another aspect combinable with any of the previous aspects further includes a top liner anchor positioned within the housing and connected to the second end of the flexible wellbore liner configured to release the second end of the flexible wellbore liner subsequent to sealing the flexible wellbore liner against the wellbore.

Another aspect combinable with any of the previous aspects further includes a float housing coupled to the top liner anchor and moveable, based on an uphole movement of the tubular work string, within the housing to deploy the flexible wellbore liner from the housing.

In another aspect combinable with any of the previous aspects, the top liner anchor is configured to socket into a disengagement ring within the housing to direct the fluid resin pumped through the flow path to an inner volume of the deployed flexible wellbore liner.

In another aspect combinable with any of the previous aspects, the float housing includes a float configured to seal fluid resin within the inner volume of the deployed flexible wellbore liner.

In another aspect combinable with any of the previous aspects, the top liner anchor, the float housing, the disengagement ring, and the float are configured to detach from the housing based on rotation of the tubular work string.

In another aspect combinable with any of the previous aspects, the detachable nose assembly includes a nose body that encloses a shuttle and a snap ring that at least partially encircles an end of the shuttle.

In another aspect combinable with any of the previous aspects, the shuttle is configured to move within the nose body based on the fluid pressure to urge the snap ring into a groove formed on an inner surface of the nose body to hold the one or more retractable grips anchored to the wellbore wall.

Another aspect combinable with any of the previous aspects further includes at least one stabilizer mounted on an outer surface of the housing and configured to centralize the housing in the wellbore.

In another example implementation, a method for installing a liner in a wellbore is defined in claim <NUM>.

An aspect combinable with the example implementation further includes circulating the fluid resin through one or more ports of a flow crossover sub-assembly positioned in the housing and into the wellbore through the housing while the flow crossover sub-assembly is in a first position; based on the fluid pressure, breaking one or more shear pins that couples the flow crossover sub-assembly to the housing to move the flow crossover sub-assembly from the first position to a second position to fluidly decouple the one or more ports from the wellbore; and with the flow crossover sub-assembly in the second position, circulating the fluid resin to anchor the one or more retractable grips to the wellbore wall.

In another aspect combinable with any of the previous aspects, the housing includes an index pin.

Another aspect combinable with any of the previous aspects further includes, during movement of the flow crossover sub-assembly from the first position to the second position, causing the flow crossover sub-assembly to rotate based on the index pin riding in a groove formed on an outer surface of the flow crossover sub-assembly; stopping rotation and movement of the flow crossover sub-assembly in the second position based on the index pin positioned in a slot formed in the groove; and maintaining the flow crossover sub-assembly at the second position based on the index pin positioned in the slot formed in the groove.

Another aspect combinable with any of the previous aspects further includes releasing the second end of the flexible wellbore liner from a top liner anchor positioned within the housing subsequent to sealing the flexible wellbore liner against the wellbore.

Another aspect combinable with any of the previous aspects further includes moving the tubular work string uphole; and based on moving the tubular work string uphole, moving a float housing coupled to the top liner anchor within the housing to deploy the flexible wellbore liner from the housing.

Another aspect combinable with any of the previous aspects further includes sealing fluid resin within the inner volume of the deployed flexible wellbore liner with a float coupled to the float housing.

Another aspect combinable with any of the previous aspects further includes rotating the tubular work string; and based on the rotation, detaching the top liner anchor, the float housing, the disengagement ring, and the float from the housing.

Another aspect combinable with any of the previous aspects further includes moving the shuttle within the nose body based on the fluid pressure to urge the snap ring into a groove formed on an inner surface of the nose body; and with the snap ring in the groove, holding the one or more retractable grips anchored to the wellbore wall.

Another aspect combinable with any of the previous aspects further includes, during movement of the downhole liner delivery tool on the tubular work string within the wellbore, centralizing the housing in the wellbore with at least one stabilizer mounted on an outer surface of the housing.

Implementations according to the present disclosure may include one or more of the following features. For example, implementations of a downhole liner delivery tool can reduce or mitigate a loss of drilling fluids into a subterranean formation. Further, implementations of a downhole liner delivery tool can provide for a more uniform dimension, or gauge, of a wellbore for drilling operations. Further, implementations of a downhole liner delivery tool may reduce the probability of wellbore collapse where formations are susceptible to such. Further, implementations of a downhole liner delivery tool can create an effective pressure barrier or seal with minimal drilled wellbore diameter reduction. (for example, with a relatively thin liner). Further, implementations of a downhole liner delivery tool can be implemented as part of a BHA. In other examples, implementations of a downhole liner delivery tool can be run as the lowest tool on a dedicated intervention run in a workstring. Further, implementations of a downhole liner delivery tool can be mechanical and actuated on demand from a terranean surface (for example, using a dropped member, such as a ball) or can be electromechanical with downlink commands used instead of a dropped member to actuate a liner deployment assembly of the tool. As another example, implementations of a downhole liner delivery tool can deploy a flexible liner, which is impregnated and then filled with, for example, a resin and inflated to the wellbore diameter to seal the formation. As another example, implementations of a downhole liner delivery tool can include a liner that cures in place to form a hard "pipe in pipe" barrier with a resin plug on the inner diameter. As a further example, implementations of a downhole liner delivery tool can include "leave in place" components that can be drilled through in a subsequent drilling operation. As another example, implementations of a downhole liner delivery tool can be used to stop fluid losses to the formation as quickly as possible and also avoid high loss rates of any remedial fluid or solids that are pumped into the well to cure the losses, which can be washed away into the formation before they have time to set and plug the holes. As a further example, implementations of a downhole liner delivery tool can provide a mechanical barrier, which holds a chemical (resin or cement) in place as it cures in the form of a combination of resin and liner material, which also has high pressure retaining ability when cured. Thus, savings of hundreds of thousands if not millions of dollars can be achieved with the example implementations of the a downhole delivery tool according to the present disclosure.

The details of one or more implementations of the subject matter described in this disclosure are set forth in the accompanying drawings and the description.

<FIG> are schematic illustrations of an example implementation of a wellbore system <NUM> that includes a downhole liner delivery tool <NUM> during an operation to deploy a wellbore liner. Generally, the downhole liner delivery tool <NUM> can be operated to place a non-permeable or semi-permeable membrane across a formation section of a wellbore in a subterranean geologic formation. The membrane, in some aspects, may be capable of reducing drilling fluid losses during a drilling operation to form the wellbore. For example, drilling fluid loss mitigation through use of the membrane system of the downhole liner delivery tool <NUM> may help speed up drilling operations or continue interrupted drilling operations, or both.

As shown in <FIG>, the wellbore system <NUM> includes a rig <NUM> (for example, a workover rig) that is positioned on a terranean surface <NUM> and over a wellbore <NUM> that is formed from the terranean surface <NUM> into one or more subterranean formations that include, for example, cracks <NUM> (also called voids or widths) that emanate from the wellbore <NUM> and cause lost circulation of a wellbore fluid. In this example, one or more casings <NUM> can be installed in the wellbore <NUM> uphole of the cracks <NUM>.

As shown in this example, the downhole liner delivery tool <NUM> can be run into a wellbore <NUM> on a work string <NUM> (for example, a tubular work string that is threadingly coupled to the downhole liner delivery tool <NUM>) as part of a BHA. The work string <NUM> that is coupled to the downhole liner delivery tool <NUM> may be moved through the wellbore <NUM> to one or more particular depths of the wellbore <NUM>, such as, for example, to a location (or vertically adjacent a location) in which drilling fluid was lost or would be lost into a subterranean (for example, rock formation, geologic formation) from the wellbore <NUM> through cracks <NUM>. Such losses may occur, for example, due to inconsistent wellbore dimensions (for example, varying diameter of the wellbore <NUM> over a vertical section of the wellbore <NUM> between the terranean surface <NUM> and a bottom of the wellbore), low-pressure formations, fissures and fractures, sand, or the geologic properties of the formation.

As shown in <FIG>, the downhole liner delivery tool <NUM> is run into the wellbore <NUM> until a downhole end of the tool <NUM> is positioned downhole of the cracks <NUM> (or, for example, downhole from where a liner is to be deployed in the wellbore <NUM>. Turning briefly to <FIG>, these figures show schematic illustrations of an example implementation of the downhole liner delivery tool <NUM>. As shown in <FIG>, the downhole liner delivery tool <NUM> includes an upper sub-assembly (or "upper sub") <NUM> and a lower sub-assembly (or "lower sub") <NUM> that can be coupled together when running in the wellbore <NUM>, such as through a threaded connection <NUM>. For instance, the threaded connection <NUM> can be threaded into the lower sub-assembly <NUM> (as shown by the dashed line).

In this example, the upper sub <NUM> includes a housing <NUM> (that can be threaded onto the conveyance <NUM> or attached to a BHA) and an upper sub stabilizer <NUM> that can act as a centralizer (for instance, to help maintain the downhole liner delivery tool <NUM> at or near a central radial axis of the wellbore <NUM> during operation). An index pin <NUM> is positioned in the housing <NUM>, as are circulation ports <NUM>. In this example, the circulation ports <NUM> (which can number <NUM>, <NUM>, or more) allow fluid communication between an inner volume of the housing <NUM> and the wellbore <NUM>. Shear pins <NUM> are positioned in the housing <NUM>. As describes, the threaded connection <NUM> is formed at a downhole end of the upper sub <NUM>. As shown in <FIG>, the top liner anchor <NUM> extends from the housing <NUM>, as does a portion of a wellbore liner (or "liner") <NUM>. In some aspects, the liner <NUM> can be made of woven fabric such as glass fiber, Aramid, or carbon fiber.

Turning to <FIG>, the lower sub <NUM> includes a housing <NUM> that can be coupled (for example, threadingly) to the threaded connection <NUM>. A lower sub stabilizer <NUM> is positioned on the housing <NUM> and can act as a centralizer (for instance, to help maintain the downhole liner delivery tool <NUM> at or near a central radial axis of the wellbore <NUM> during operation). Lower sub shear pins <NUM> are positioned on the housing <NUM>, as is a nose assembly <NUM> that defines a downhole end of the downhole liner delivery tool <NUM>.

Turning now to <FIG>, these figures show schematic cross-sectional illustrations of the example implementation of the downhole liner delivery tool <NUM> of <FIG>. For example, <FIG> shows a schematic cross-sectional illustration of the upper sub <NUM> of the downhole liner delivery tool <NUM> in a running in position (for example, as shown in <FIG>). The upper sub <NUM> includes, positioned within the housing <NUM>, a downhole conveyance connection <NUM> (that connects the tool <NUM> to the conveyance <NUM>), a flow crossover sub-assembly <NUM> that includes the ports <NUM>, a float housing <NUM>, a float <NUM>, and the top liner anchor <NUM> (which includes a seal <NUM>). In this example, the liner <NUM> is connected to the top liner anchor <NUM> (during the deployment process, prior to disconnect). As shown in <FIG>, during the run in process, the float housing <NUM> is secured to the housing <NUM> with shear pins <NUM>, and the index pin <NUM> couples the flow crossover sub-assembly <NUM> to the housing <NUM> (which can move relative to each other as described later).

<FIG> shows a schematic cross-sectional illustration of the lower sub <NUM> of the downhole liner delivery tool <NUM> in the running in position (for example, as shown in <FIG>).

Turning now to <FIG>, a schematic cross-sectional illustration of the lower sub <NUM> of the downhole liner delivery tool <NUM> is shown. The lower sub <NUM> includes the nose assembly <NUM> into which the liner <NUM> is anchored opposite its anchoring location in the top liner anchor <NUM>. Thus, during the run-in process, the liner <NUM> is connected at the top liner anchor <NUM> and the nose assembly <NUM>. Although <FIG> show only the anchored portions of the liner <NUM>, the liner <NUM> is stored and extends within the housing <NUM> from the top liner anchor <NUM> to the nose assembly <NUM> in the initial run-in position as shown.

Turning briefly to <FIG>, these figures show schematic illustrations of the liner <NUM> of the downhole liner delivery tool <NUM> as stored within the tool <NUM> prior to deployment in the wellbore <NUM>. For example, in some aspects, the liner <NUM> can be, when deployed from the tool <NUM>, much longer than the housing <NUM>. Thus, when stored, the liner <NUM> can be folded or rolled within the housing <NUM>. As shown in <FIG>, for instance, in an example aspect of the downhole liner delivery tool <NUM>, the liner <NUM> can be flattened and folded in a lengthwise direction to be stored within the housing <NUM> (not shown here) while connected between the top liner anchor <NUM> and the nose assembly <NUM>. As shown in <FIG>, a liner <NUM> of a circular cross-section (when expanded), can be compressed into a relatively flat position to be stored prior to deployment. For a liner <NUM> that is, for instance, about <NUM> (<NUM> inches) in outer diameter when radially expanded, the flattened liner <NUM> can be about <NUM> (<NUM> inches) in width to be stored in the housing <NUM>. As another example, <FIG> shows the liner <NUM> stored in the housing <NUM> in a rolled position.

Turning now to <FIG>, these figures show schematic cross-sectional illustrations of the nose assembly <NUM> of the downhole liner delivery tool <NUM>. As shown in this example implementation, the nose assembly <NUM> includes a nose body <NUM> that is coupled to the housing <NUM> with shear pins <NUM>. A disengagement ring <NUM> is also detachably coupled to the housing <NUM> and abuts the nose body <NUM>. The liner <NUM> is coupled to a main nose anchor <NUM>, which is threaded within a shuttle <NUM>. Further connecting the liner <NUM> to the nose assembly <NUM> is a male nose anchor <NUM> which is threaded within a female nose anchor <NUM>. The shuttle <NUM> extends into the nose body <NUM> and radially abuts expanding pads <NUM>. As explained in more detail later, the expanding pads <NUM> include grips or teeth that can attach to the wellbore <NUM> (or a casing within the wellbore <NUM>, or both) to secure the nose assembly <NUM> at a particular location in the wellbore <NUM>).

Turning back to <FIG>, this figure shows the downhole liner delivery tool <NUM> during a deployment operation to deploy the liner <NUM> out of the housing <NUM> and into the wellbore <NUM> while still connected to the main nose anchor <NUM> and the top liner anchor <NUM>. A more detailed description of this process is described with reference to <FIG>, which are schematic illustrations of an example implementation of the downhole liner delivery tool <NUM> during the deployment operation.

Turning to <FIG>, as shown, to being the deployment operation, a wellbore fluid <NUM> is circulated from the terranean surface <NUM>, through the downhole conveyance <NUM>, and into the upper sub <NUM>. In some aspects, the wellbore fluid <NUM> can be a resin <NUM> (or epoxy or other hardeneable or semi-hardenable liquid) that can cure and attach the liner <NUM> to the wellbore <NUM>. <FIG> shows the resin <NUM> pumped through the downhole conveyance connection <NUM>, into the flow crossover sub-assembly <NUM>, and out of the ports <NUM> into an annulus between the tool <NUM> and the wellbore <NUM>. The resin <NUM> can then flow back to the terranean surface <NUM>, as <FIG> can represent a flushing out process of the tool <NUM> by circulating the resin <NUM> there through.

As shown in <FIG>, to activate the downhole liner delivery tool <NUM> to start the deployment operation, a member <NUM> (such as a ball <NUM>) is circulated with the resin <NUM> from the terranean surface <NUM> and lands on a seat <NUM> formed in the flow crossover sub-assembly <NUM>. In some aspects, the ball <NUM> can be made of an extrudable material and have a density similar to the resin <NUM> being pumped. The ball <NUM> can be pumped down with some resin <NUM> ahead of it to flush out any mud in the conveyance <NUM> and avoid contamination of the liner <NUM> (as described in <FIG>).

As pressure increases uphole of the ball <NUM> by the circulated resin <NUM>, the flow crossover sub-assembly <NUM> is urged downward and as the pressure force increases, shear pins <NUM>, which hold the flow crossover sub-assembly <NUM> and the float housing <NUM> in position, are broken. As shown in <FIG>, once the shear pins <NUM> are broken, movement <NUM> occurs and the flow crossover sub-assembly <NUM> moves down and opens a flow path to an inner bore of the upper sub <NUM>.

Movement of the flow crossover sub-assembly <NUM> is stopped by the index pin <NUM>, which, in this example, rides in a groove formed on the flow crossover sub-assembly <NUM> until it stops in the correct position and also prevents reverse motion, which would open the circulation ports <NUM> to the annulus. Thus, in the configuration of the downhole liner delivery tool <NUM> shown in <FIG>, the circulation ports <NUM> are now fluidly decoupled from the annulus.

Turning briefly to <FIG>, this figure shows the flow crossover sub-assembly <NUM> of the downhole liner delivery tool <NUM> and the groove <NUM> in which the index pin <NUM> can ride. As shown, the groove <NUM> wraps radially around an outer diameter of the flow crossover sub-assembly <NUM> and includes, at an uphole end, a slot <NUM>. When the flow crossover sub-assembly <NUM> is moved downward in movement <NUM>, the travel path of the index pin <NUM> within the groove <NUM> (which begins at a downhole end of the groove <NUM>) causes the flow crossover sub-assembly <NUM> to rotate. The length and angle of the groove <NUM> can control the amount of rotation and the allowable downhole movement distance during movement <NUM>. When the index pin <NUM> hits the uphole end of the groove <NUM> at which the slot <NUM> is formed, movement stops. And, if later, a pressure directed in an uphole direction tries to move the flow crossover sub-assembly <NUM> back uphole, then the index pin <NUM> drops into the slot <NUM> and prevents such uphole movement.

Turning now to <FIG>, as pressure from the resin <NUM> is increased further, the ball <NUM> can be extruded through the seat <NUM> and lands in the catch <NUM>. The resin <NUM>, with the ports <NUM> now closed to the annulus, circulates from the ports <NUM> into a bypass <NUM> (between the upper sub stabilizer <NUM> and the flow crossover sub-assembly <NUM>) and then into an inner diameter of the float housing <NUM>. When the flow of the resin <NUM> reaches ports <NUM>, the resin <NUM> exits the inner diameter of the float housing <NUM> and flows out over the outer diameter of the float housing <NUM> to the housing <NUM> that encloses the liner <NUM>. Turning briefly to <FIG>, this figure illustrates the flow of the resin <NUM> out over the float housing <NUM> and the top anchor lock <NUM> (a portion of which are enclosed in the housing <NUM> and the housing <NUM>) and to the liner <NUM> (which is enclosed in the housing <NUM>). During this step of the operation, the resin <NUM> begins to soak into the liner <NUM> inside the housing <NUM>.

Turning now to <FIG>, these figures are schematic illustrations of the nose assembly <NUM> of the downhole liner delivery tool <NUM> once the resin <NUM> is pumped over the liner <NUM> and to the nose assembly <NUM> in order to anchor the nose assembly <NUM> to the wellbore <NUM>. Turning to <FIG>, this figures shows the resin <NUM> flowing to, and then filling, the nose body <NUM>. As the resin <NUM> fills the nose body <NUM>, pressure is applied to create movement <NUM> of the shuttle <NUM>. As the shuttle <NUM> moves with movement <NUM>, a shoulder <NUM> of the shuttle <NUM> pushes the expanding pads <NUM> outward with movement <NUM> (shown in <FIG>). As the expanding pads <NUM> are urged outward, the pads <NUM> engage the wellbore <NUM> with grips <NUM> to prevent uphole movement and anchor the nose assembly <NUM> to the wellbore <NUM> (or casing in the wellbore <NUM>). <FIG> shows the nose assembly <NUM> anchored to the wellbore <NUM>.

Once the shuttle <NUM> is urged with movement <NUM> toward a downhole end of the nose assembly <NUM>, a lock ring <NUM> that is positioned radially around the shuttle <NUM> snaps into a groove <NUM> formed on an interior surface of the nose body <NUM>. Once snapped into the groove <NUM>, the lock ring <NUM> holds the shuttle <NUM> in place, which also holds the expanding pads <NUM> in a radially expanded position against the wellbore <NUM>.

Turning briefly to <FIG>, these figures show schematic illustrations of the shuttle <NUM> and shuttle lock ring <NUM>, respectively, of the downhole liner delivery tool <NUM>. As shown, in this example implementation, the lock ring <NUM> is comprises of a split ring that includes threads <NUM> formed on an inner radial surface. The shuttle <NUM> also includes corresponding threads <NUM> that can engage the threads <NUM> (and disengage, as described later).

Turning now to <FIG>, this figure shows a step of the deployment operation in which the nose assembly <NUM> is released from the housing <NUM>, while being anchored to the wellbore <NUM>. As the pressure of the resin <NUM> is increased, shear pins <NUM> are broken, which releases the nose body <NUM> from the housing <NUM>. Once released, the housing <NUM> (and disengagement ring <NUM>) can be moved uphole by uphole movement of the conveyance <NUM>. While the housing <NUM> is moved uphole, the liner <NUM> remains connected to the nose body <NUM> but plays out from the housing <NUM> during such movement. At this point, the liner <NUM> can be exposed to the fluids in the wellbore annulus (resin again) for the first time. With the nose assembly <NUM> anchored in place, the tool <NUM> is pulled back up the wellbore <NUM> and this pulls the liner <NUM> from the housing <NUM>. In some aspects, the pull-back distance can be measured so that the liner <NUM> is not over or under deployed.

Turning to <FIG>, these figures show schematic illustrations the further steps of the deployment operation of the downhole liner delivery tool <NUM>. Turning to <FIG>, these figures show the housing <NUM> pulled back (uphole) from the nose assembly <NUM> in order to deploy the liner <NUM> into the wellbore. This is also shown in <FIG>. At this part of the deployment operation, the liner <NUM> is still attached to the top liner anchor <NUM> as well as the nose assembly <NUM>.

In order to further deploy the liner <NUM> in the wellbore <NUM>, additional resin <NUM> can be circulated into the tool <NUM> to expand the liner <NUM>. Turning to <FIG>, movement uphole of the conveyance <NUM> (and thus tool <NUM>), operates to create movement <NUM> so that the float housing <NUM> detaches from the flow crossover sub-assembly <NUM> and slides downward.

Turning to <FIG>, as shown, the resin <NUM> can be diverted into the inner diameter of the liner <NUM> in order to inflate it. As the liner <NUM> is deployed, the uphole movement of the tool <NUM> and the float housing <NUM> is detached from the flow crossover sub-assembly <NUM>, the float housing <NUM> is pulled to the downhole end of the housing <NUM> as shown in <FIG>. When the float housing <NUM> detaches from the flow crossover sub-assembly <NUM>, the flow of the resin <NUM> which was diverted from the inner diameter of the float housing <NUM> can now flow into the inner diameter of the float housing <NUM>, through the float <NUM> and into the liner <NUM>. In some aspects, a seal, such as an O-ring on the outer surface of the float housing <NUM> can prevent flow of the resin <NUM> from bypassing the interior of the liner <NUM>.

As further shown in <FIG>, uphole movement of the tool <NUM> can cause the top liner anchor <NUM> to socket into the disengagement ring <NUM> at a downhole end of the housing <NUM> of the lower sub <NUM>. Turning briefly to <FIG>, these figures show schematic illustrations of the top liner anchor <NUM> and disengagement ring <NUM>. The disengagement ring <NUM> sockets onto the top liner anchor <NUM> until it is past and uphole of the anchor seal <NUM>. Flow of the resin <NUM> can now be through the inner diameter of the float housing <NUM> and float <NUM> and into the inner diameter of the liner <NUM>. In this example, as shown, the seal <NUM> acts as an anchor lock to prevent the top liner anchor <NUM> from backing out of the disengagement ring <NUM> (in other words, disengaging while moving uphole) once socketed together.

Once the top liner anchor <NUM> sockets onto the disengagement ring <NUM>, the liner <NUM> can be further expanded onto the wellbore <NUM> by further circulation of resin <NUM>. For example, turning to <FIG>, the resin <NUM> is further circulated into the inner diameter of the liner <NUM>, causing the liner <NUM> to expand against the wellbore <NUM> (or a casing installed in the wellbore <NUM>). The liner <NUM>, once expanded, can seal off any cracks <NUM> as shown in <FIG>.

Once the liner <NUM> seals off the cracks <NUM>, the liner <NUM> can be released from at least a portion of the downhole liner delivery tool <NUM>, so that the tool <NUM> can be run out of the wellbore <NUM> on the conveyance <NUM>. For example, turning to <FIG>, as shown, the tool <NUM> can be manipulated so that the housing <NUM> releases to allow the liner <NUM> (attached to the top liner anchor <NUM> and float <NUM>) within the wellbore <NUM>.

In this example, as shown in <FIG>, the disengagement ring <NUM> and the top liner anchor <NUM> can include castellations (or any other feature which will allow two parts to socket together and transmit torque). The downhole conveyance <NUM> (in this example, a drill string) can be rotated such that the disengagement ring <NUM> unscrews from the housing <NUM>. The disengagement ring <NUM>, float housing <NUM>, float <NUM>, and the top liner anchor <NUM> can then be released from the housing <NUM> as shown in <FIG>. In some aspects, the float <NUM> can prevent (or help prevent) any resin <NUM> that is inside the liner <NUM> from flowing back uphole (for example, by maintaining a positive pressure) after the liner <NUM> is released from the remaining portion of the tool <NUM>. The end result of the deployment operation is also shown in <FIG>, as well as <FIG> (which shows a non-sectional view of the tool <NUM>).

While this specification contains many specific implementation details, these should not be construed as limitations on the scope of any claims or of what may be claimed, but rather as descriptions of features specific to particular implementations. Moreover, although features may be described as acting in certain combinations and even initially claimed as such, one or more features from a claimed combination can in some cases be excised from the combination, and the claimed combination may be directed to a subcombination or variation of a subcombination.

Claim 1:
A downhole liner delivery tool comprising:
a housing (<NUM>) configured to couple to a tubular work string (<NUM>), the housing comprising a flow path;
a detachable nose assembly (<NUM>) releasably coupled to a downhole end of the housing and fluidly coupled to the flow path, the detachable nose assembly (<NUM>) comprising one or more retractable grips (<NUM>) positioned at an external surface of the detachable nose assembly and configured to secure the nose assembly (<NUM>) to a wellbore;
a flexible wellbore liner (<NUM>) comprising a first end coupled to the detachable nose assembly and a second end coupled within the housing (<NUM>), the flexible wellbore liner (<NUM>) stored within the flow path of the housing;
a seat (<NUM>) formed in the flow path and configured to receive a member (<NUM>) dropped in a wellbore from a terranean surface, the receipt of the member by the seat configured to increase a fluid pressure of a fluid resin (<NUM>) pumped through the flow path, wherein the flow path couples the fluid pressure to a body (<NUM>) of the detachable nose assembly (<NUM>) to expand the one or more retractable grips (<NUM>) to engage a wellbore wall and detach the detachable nose assembly from the housing.