Abstract: A flow through assembly includes an anchoring device to secure a downhole assembly to a casing in a wellbore, the anchoring device includes a center flow channel; an upper perforated tube attached to the anchoring device, the upper perforated tube includes upper perforations and an upper flow channel fluidly connected to the center flow channel; and a lower perforated tube attached to the anchoring device, the lower perforated tube includes lower perforations and a lower flow channel, wherein gas can flow through the lower perforations to enter the lower flow channel of the lower perforated tube, through the lower flow channel, through the center flow channel, then exit through the upper perforations of the upper flow channel.

Abstract: Disclosed is a fluid-driven dual-mode circulation tool which is suitable for high-temperature applications, and which is operable to switch between a flow-through mode and an annular-flow mode. Switching modes is accomplished by interrupting (or reducing) and then reinstating the flow of pressurized fluid through it. In the flow-through mode, pressurized fluid flows out of the tool into the bottom hole assembly. In the annular-flow mode, the tool diverts fluid through internal paths that access the annulus of the wellbore or casing through one or more apertures on the sidewall of the tool.

Abstract: Regulating downhole fluid flow through a plurality of valves to treat wellbore sections while also allowing for production to continue. If it is determined that fluid flow through a valve of a plurality of valves is below a threshold, maintaining fluid flow through the below threshold valve may be maintained while restricting fluid flow through other valves of the plurality. This restriction fluidly isolates a section of a well from other sections of the well. Once isolated, a treatment substance may be injected through the below threshold valve into the isolated section of well. Afterwards, the closed valves may be reopened while restricting fluid flow through the treated section valve for a threshold period of time. the treated section valve may then be reopened after the threshold period of time.

Abstract: A well system includes a wellbore, production tubing extended into the wellbore and thereby defining an annulus between the production tubing and an inner wall of the wellbore, and a side pocket mandrel interposing upper and lower sections of the production tubing and including a body that provides a lateral projection extending radially outward from the body, and a pocket defined within the lateral projection. The well system further includes a chemical vessel receivable within the pocket and operable to discharge an injection fluid stored within the chemical vessel into the production tubing via one or more apertures provided in the chemical vessel.

Abstract: A downhole shifter tool assembly configured to operate a downhole tool. The shifter tool assembly comprises a anchor tool, an extension tool, a shifting key, and a standoff spacer. The standoff spacer is configured to locate the shifter tool assembly at a reference position by contacting an isolation member on the downhole tool. An anchoring mechanism within the anchor tool can anchor the shifter tool assembly in the reference position. An extend-retract mechanism within the extension tool can extend move the shifting key on a shifting tool into engagement with a shifting profile on the downhole tool and move the shifting profile to a second position. The downhole tool can be operated by the shifting key moving the shifting profile from an initial position to the second position.

Abstract: A system and a method for clearing debris from the top of plug in a well are provided. In an exemplary system a plug for a well includes a cylindrical body, a sealing ring mounted in the cylindrical body, and a flapper valve disposed against the sealing ring in the cylindrical body. The plug also includes a torsion spring to open the flapper valve when a latch on the flapper valve is disengaged, a receiver to receive control signals, and an actuator controlled by the receiver to disengage the latch.

Abstract: Downhole tool is provided that includes a body, an intake port for receiving fluid from external the body, a pump, a filtration device, and an exit port. The pump is in fluid communication with the intake port for withdrawing fluid through the intake port. The filtration device has a particulate removing filter, and a flow line extending from the intake port to the filtration device. The filtration device is contained within the body and is in fluid communication with the intake port. The exit port is in fluid communication with the filtration device for ejecting the fluid to external the body.

Abstract: A system includes rotational ball seat (RBS), remote operated, and electrical/hydraulic sections. The RBS section includes a spring, a first internal sleeve, and an upper RBS. The remote operated section includes a lower rotational ball valve (RBV) disposed between second and third internal sleeves, and a setting sleeve operatively connected to the lower RBV. During miming-in-hole, the upper RBS is in a restricted position, and the lower RBV is in an open position. The spring compresses the internal sleeves, which sandwich the upper RBS and the lower RBV, until a shear event occurs. An inner diameter of the system closes to facilitate setting of hydraulic equipment. Thereafter, the shear event releases the spring, thereby pushing the internal sleeves, the upper RBS, and the lower RBV downhole, which rotates the upper RBS and the lower RBV into open positions, thereby opening the inner diameter of the system.

Abstract: A pure electric modular subsea test tree is provided, which includes a connect-disconnect device, wherein the first channel is formed in the connect-disconnect device; the connect-disconnect device is provided with a locking assembly and a connection drive mechanism for driving the locking assembly, and the first electrical connection plug is embedded in the connect-disconnect device, and the connection drive mechanism is electrically connected with the first electrical connection plug; a shear-seal assembly, wherein a second channel communicated with the first channel is formed in the shear-seal assembly; the shear-seal assembly includes at least one shear-seal device capable of plugging the second channel; a connection part is formed on the shear-seal assembly; a heating device is arranged at one end of the shear-seal device far from the connection part. The disclosure relates to a pure electric modular subsea test tree, which has fast response speed and high operation safety.

Abstract: A linear escapement mechanism is provided for actuating a downhole tool in a controlled and predictable manner, such as in response to a certain number of pressure cycles. In an example, the actuator includes an escapement sleeve axially moveable with respect to an actuator housing. The escapement sleeve has a plurality of axially-arranged escapement teeth. A rocker secured within the actuator housing has opposing first and second pallets. An operating sleeve is reciprocable to rock the rocker back and forth to alternately move the opposing first and second pallets into engagement with the escapement sleeve as the escapement sleeve advances axially in an actuating direction.

Abstract: An assembly comprises a tubular housing having a bore therethrough and at least one stimulation port therein to communicate fluid from the bore to outside the tubular housing and a sleeve axially movable in the tubular housing. The sleeve comprises a first baffle and a second baffle. The sleeve is initially in a first closed position, wherein the sleeve is to axially move from the first closed position to an open position in response to the first baffle receiving a first object therein, wherein the at least one stimulation port is open in the open position. The sleeve is to axially move from the open position to a second closed position in response to the second baffle receiving a second object received therein, wherein the second object is larger than the first object, where the at least one stimulation port is closed in the second closed position.

Abstract: Systems and a method for resisting a fluctuation in a value of a parameter relating to well equipment using a magnetorheological dampener system are described herein. The method includes continuously determining the value of the parameter relating to the well equipment, determining a fluctuation in the value of the parameter, and comparing the fluctuation in the value of the parameter to a preset limit. The method also includes energizing an electromagnet to increase a viscosity of a magnetorheological fluid (MRF) if the fluctuation exceeds the preset limit.

Abstract: A first interval inflow control device and a second interval inflow control device are positioned on a production tubing string proximate to a first subterranean interval and a second subterranean interval, respectively. The inflow control devices each include a central bore, a sand screen surrounding an inner tube, a plurality of ports connect the annular space between an inner surface of the sand screen and an outer surface of the inner tube, and a sliding sleeve configured to translate between an open position and closed position. A first shifting tool is configured to engage with and axially translate the sliding sleeve of the first interval inflow control device and a second shifting tool is configured to engage with and axially translate the sliding sleeve of the second interval inflow control device. The second shifting tool has an outer diameter less than the bore of the first interval inflow control device.

Abstract: This application discloses an improved downhole assembly for separating oil and gas in an oil well. A flow through assembly is disclosed wherein separated gas may pass an anchoring device with less restriction. The improved flow through assembly allows for separated gas to pass through the center flow channel of an anchoring device.

Abstract: A downhole valve, such as a safety valve or sub-sea safety valve (SSSV). The downhole valve comprising: a housing; a flow path between a valve inlet and a valve outlet; a valve mechanism; and a piston member; wherein the valve mechanism is operable by actuation of the piston member to selectively open and close the flow path between the valve inlet and valve outlet; and the piston member is actuatable by a pressure differential between an annulus pressure at the valve and a pressure at the valve outlet and/or in a portion of the flow path closest to the valve outlet. The valve can comprise an opening for receiving the annular pressure that is isolated from the valve inlet and valve outlet. The downhole valve can be configured such that it prevents operation of the valve mechanism to open and/or close the flow path by a pressure differential between the valve inlet and valve outlet.

Abstract: A ball valve assembly includes a ball having a fluid pathway and a leading edge portion. The ball is configured to rotate between an open position and a closed position, the fluid pathway is configured to align with a fluid passage while the ball is in the open position, and the fluid pathway is configured to be offset from the fluid passage while the ball is in the closed position. Furthermore, the leading edge portion includes a first leading edge configured to cut a line extending through the fluid pathway as the ball rotates from the open position to the closed position, the leading edge portion includes a second leading edge configured to engage a seal of the ball valve assembly as the ball rotates from the open position to the closed position, and the first leading edge is positioned radially inward from the second leading edge.

Abstract: A technique facilitates operation of a valve system a having combined valve such as a combined formation isolation valve and a circulating valve. In well operations, the valve system is deployed downhole into a wellbore on a tubing string. The formation isolation valve and the circulating valve are operable independently via inputs, e.g. hydraulic inputs provided through less than three hydraulic control lines. The formation isolation valve and the circulating valve may be coupled by a mechanical linkage, which enables operation of the two valves via the hydraulic control lines. In some embodiments, the formation isolation valve and the circulating valve may be operated via an integrated shifting tool.

Abstract: A gas-lift valve in a wellbore may include a valve housing and a flow restrictor. The valve housing may at least in part define a chamber for receiving an actuation fluid. The flow restrictor may have a position that is controllable by adjusting a downhole pressure to change a density of the actuation fluid in the chamber. The gas-lift valve may be positioned on production tubing in an annulus of a wellbore. Controlling the position of the flow restrictor may restrict an opening in the production tubing through which gas may flow.

Abstract: A method includes deploying a cementing assembly within a wellbore. The wellbore includes a loss circulation zone. The cementing assembly includes a work string and a liner assembly coupled to the work string. The liner assembly includes a polished bore receptacle, a liner hanger attached to a downhole end of the polished bore receptacle, a liner, and a cementing sub disposed between the liner hanger and the liner. The method includes anchoring the liner hanger on the casing of the wellbore, cementing an open hole annulus of the wellbore, and setting an annulus packer of the cementing sub on the. The method also includes cementing a casing annulus of the wellbore defined between an external surface of the cementing sub and a wall of wellbore.

Abstract: Logging downhole exposes components of logging tools, for example, antennas to abrasive and erosive operating conditions. A protective sleeve may disposed about an antenna assembly to protect the antenna assembly for the downhole operating conditions. To permit transmission and receipt of signals by and too the antenna assembly, slots are formed or disposed in the protective sleeve. A non-conductive composite insert is formed in the slots to protect the internal components of the protective sleeve, for example, the antenna assembly, from the operation conditions. A non-conductive composite inner liner is formed in an annulus of the protective sleeve and adheres to the protective sleeve and the non-conductive composite insert. The non-conductive component insert and inner liner allow signals to be transmitted and received by the antenna assembly so that logging operations can be completed without undue delay and the expense of repairing or replacing worn or damaged components.

Abstract: A tubular cleaning system includes a housing having an outer surface, an inner surface, and a recess. A deployable tool is arranged in the recess. A motor is arranged in a cavity formed the housing between the outer surface and the inner surface. An actuator is operatively connected between the motor and the deployable tool. The motor is selectively activated through a signal to extend the deployable tool.

Abstract: A well pump assembly has a tubular receptacle for attachment to a lower end of a string of production tubing. A docking station mounts to the receptacle, the docking station having a lower well fluid conduit for receiving well fluid from the well, a lower orientation guide, and a lower hydraulic connector. A hydraulic line extends alongside the receptacle and is in fluid communication with the lower hydraulic connector for supplying hydraulic fluid. A hydraulically actuated pump is configured to be lowered into and retrieved from the receptacle. A guide member on a lower end of the pump has an upper orientation guide, and an upper hydraulic connector in fluid communication with the pump, and an upper well fluid conduit leading to an intake of the pump.

Abstract: A modular downhole packer includes a valve body, which includes a threaded coupler adapted to couple to a tubular and a valve assembly. The packer includes a packer element assembly, which includes a first end coupler, the first end coupler mechanically coupled to the valve body; a packer element; and a second end coupler. The packer includes a floating seal element mechanically coupled to the second end coupler, the floating seal element including a seal extension. The packer includes a floating end anchor. The floating end anchor includes a compression seal housing, the compression seal housing including an outer sealing surface positioned within the seal extension of the second end coupler; a compression seal positioned within a seal pocket formed in the compression seal housing; and an anchor body, the anchor body threadedly coupled to the seal pocket of the compression seal housing, the anchor body abutting the compression seal.

Abstract: A wellbore assembly includes a wellbore string configured to be disposed within a wellbore. The wellbore assembly also includes a float collar coupled to a downhole end of the wellbore string. The float collar includes a housing, a check valve, and a sleeve. The housing includes a fluid outlet. The housing defines a fluid port that extends through a wall of the housing. The check valve is disposed within the housing between the fluid port and the fluid outlet. The sleeve is coupled to the wall of the housing uphole of the check valve. The sleeve moves, based on pressure changes of the fluid in the float collar, with respect to the wall of the housing thereby either exposing the fluid port and opening a fluid pathway from the bore to an annulus of the wellbore, or covering the fluid port and blocking the fluid pathway.

Abstract: A mechanically actuated tubing drain for service with oil wells, water wells, gas wells and/or thermal wells has a configuration in which the drain opens by operation of a bumper member which may be pulled upwardly to move a sleeve member which is initially positioned adjacent to a drain port, thereby sealing the drain port. Once the bumper member pushes the sleeve member upwardly, any fluid in the tubing above the drain port will drain from the tubing. The bumper member may be pulled upwardly either by upward movement of a rod string or by operation of a wireline or slickline tool. The mechanically actuated drain does not require a tubing anchor to operate.

Abstract: There is provided a flow control apparatus configured for optimizing use of available space within the wellbore for conducting of fluids between the surface and the subterranean formation. The flow control apparatus is useable for conducting all forms of fluid, such as, for example, liquids, gases, or mixtures of liquids and gases. As well, the flow control apparatus is useable for effecting injection of fluid (e.g. a fluid for stimulating hydrocarbon production via a drive process, such as, for example, waterflooding, or via a cyclic process, such as “huff and puff”) into the subterranean formation, and for receiving production of fluid (e.g. hydrocarbon material) from the subterranean formation (including production that is stimulated by gas lift).

Abstract: Utilizing a fluid flow rate within a tool to close and open a vent extending through a circumference of the tool. The vent may be positioned above a packer pair that is configured to extend across an annulus. The tool may include a vent, sliding sleeve, adjustable member, and plunger.

Abstract: A downhole sleeve tool is provided that includes a lower sub defining a bore and one or more sleeve ports therethrough. There is a piston valve movably positionable within the lower sub to selectively block communication between the bore and the one or more sleeve ports. There is an upper sub connectable to the lower sub and sharing another bore therewith. The upper sub has an inlet port, one or more communication ports, and an outlet port. There is an at least one cartridge assembly disposed in a cartridge bore formed in a wall of the upper sub.

Abstract: A tool activation device includes a pressure inlet port configured to be in communication with a wellbore pressure, and a housing that includes a counter mechanism with a first counter end and a second counter end, where the counter mechanism includes a closed chamber filled with a fluid having a pressure, and a ratchet system that includes a ratchet piston with a first ratchet end in pressure communication with the pressure inlet port and a second ratchet end in communication with the closed chamber, a valve mechanism interconnecting the pressure inlet port and the closed chamber arranged for equalizing the pressure a cross the ratchet piston.

Abstract: A downhole tool control apparatus includes a control assembly, a stroking assembly, and a pocket sleeve positioned in an outer sub. The control assembly and stroking assembly are independently slidable axially within the outer sub. The control assembly and stroking assembly slide depending on the flow rate of fluid through the downhole tool actuator. The stroking assembly includes a spline barrel having a spline projection positioned within a spline pocket formed in the pocket sleeve. The pocket sleeve and control assembly include one or more ratchet teeth positioned in the pocket sleeve such that as the flow rate is changed between a high and a low flow rate, the spline projection engages the ratchet teeth until an actuated cycle is completed, allowing the downhole tool actuator to move to an actuation position.

Abstract: A downhole sleeve tool is provided that includes a lower sub defining a central bore and one or more sleeve ports therethrough. There is a piston valve slidably positionable within the lower sub to selectively block communication between the central bore and the one or more sleeve ports. There is an upper sub connectable to the lower sub and sharing another central bore therewith. The upper sub has an inlet port, one or more communication ports, and an outlet port. There is an at least one cartridge assembly disposed in a cartridge bore formed in a wall of the upper sub.

Abstract: A mud motor stall protector including a housing, a piston translationally disposed in the housing, the piston defining a flow passage therein, and a pin positioned relative to the housing to occupy a portion of the flow passage of the piston or leave the flow passage of the piston open depending upon position of the piston relative to the pin.

Abstract: Systems and methods for drilling optimization of a subterranean well include securing a multifunction sub in line with a tubular string. A nozzle provides a fluid flow path from the central bore through a sidewall of the sub body, the nozzle oriented in a direction so that the fluid flow path directs a wellbore fluid from within the central bore in a direction uphole. A valve system can move between a closed position where the fluid flow path of the nozzle is closed, and at least one open position where the wellbore fluid can pass through the fluid flow path. A control system is operable to receive information and provide a signal to move the valve system. The tubular string is moved into a bore of the subterranean well and information is delivered to the control system to regulate the flow of wellbore fluid through the nozzle.

Abstract: There are described downhole devices, methods and other apparatus, which may be used to generate energy, monitor fluids and/or provide control signals or otherwise trigger for actuation. The devices, methods, etc. may provide improved autonomy and/or accuracy, while at the same time minimise any effect on the operation of a well. Such devices and methods may be particularly useful downhole and in remote locations. An example of a device comprises a generating material having a fluid contact surface, that contact surface being configured to be in contact with a fluid downhole. The generating material may be configured to generate an electric charge at the material in response a fluid at the contact surface. In some examples, the device further comprises a signal source configured to provide a signal in response to a generated electric charge at the generating material.

Abstract: A wellhead valve assembly feedthrough for a cable or conduit comprises a lower connector disposed within the wellhead valve assembly and being coupled to an upper end of a cable or conduit disposed in a wellbore, and a moveable upper connector disposed above the lower connector, the upper connector extensible to connect to the lower connector and retractable to disconnect from the lower connector. The wellhead valve assembly feedthrough further includes a sealed exit arrangement having a segment of conduit or cable passing therethrough to outside the wellhead valve assembly, wherein one end of the segment of conduit of cable is connected to the upper connector.

Abstract: A hydraulic arrangement for fail-safe and pump-through of a safety valve. The arrangement allows for compact actuation of a safety valve through accumulators. The arrangement supports automatic closure of the valve in the emergent circumstance of any loss of hydraulic control above the valve. Additionally, the arrangement also allows for a technique of re-opening the valve for long term killing of a well in direct response to the introduction of kill fluid without requiring any added complex interventional measures.

Abstract: A downhole cutting tool and method of operating the cutting tool. The cutting tool (10) has first and second flow pathways through the tool body (12) and a switching mechanism operated by axial force via weight-set or drop ball to control the opening of the flow pathways and direct fluid to the second flow path and operate the cutting mechanism (18). Fluid flow through the first pathway can be used to actuate a hydraulically operated tool mounted on the tool string below the cutting tool (10).

Abstract: A selective downhole actuator comprising at least a first actuator position, a second actuator position and a third actuator position. The selective downhole actuator is reconfigurable between the first actuator position and the second actuator position. The selective actuator is selectively reconfigurable to the third actuator position by varying an operating parameter during a transition of the selective downhole actuator between the first and second actuator positions.

Abstract: A splitflow valve comprises a tubular body, a valve element and a lock. The tubular body defines a through hole and has at least one lateral bypass port. The valve element defines a flow restriction and is moveable along the through hole along a first direction between a first position and a second position, wherein the bypass port is closed by the valve element in the first position. In the second position the bypass port is open. The lock maintains the valve element in the second position wherein a flow of fluid entering the through hole of the tubular body is split into a first flow portion passing the flow restriction and a second flow portion exiting the at least one bypass port. Further, the lock is deactivatable to allow the valve element to return to the first position.

Abstract: A method of controlling flow in a tubular including developing a pressure in the tubular with an electric submersible pump (ESP), directing a flow of fluid through a flow control device arranged on the tubular downhole of the ESP in response to the pressure, sensing a parameter of the flow of fluid, and adjusting, in real time, a flow parameter of the flow control device with a coil tubing in response to the parameter of the fluid.

Abstract: A tubular includes an outer surface, an inner surface defining a passage, and a plurality of openings extending through the outer surface and the inner surface. A sleeve is positioned within the passage. The sleeve includes an outer surface portion having at least one recess. At least one release member extends from the inner surface into the at least one recess. The at least one release member maintains the sleeve in a first configuration relative to the plurality of openings. At least one of the inner surface and the outer surface portion includes a self-holding connection that establishes one of a reduced diameter portion of the passage and an increased diameter portion of the sleeve. The self-holding connection is configured to maintain the sleeve in a second configuration axially shifted relative to the first configuration.

Abstract: A bypass diverter sub including a housing defining a flow passage, a control line bypass piston arranged within a control line bypass bore defined in a wall of the housing, and a balance line bypass piston arranged within a balance line bypass bore defined in the wall. An outer magnet is disposed within a magnet chamber and is operatively coupled to the control and balance line bypass. A flow tube profile is positioned within the flow passage and provides an inner magnet magnetically coupled to the outer. The flow tube profile is movable between a first position, where control line and balance line pressures circulate through the bypass diverter sub to a subsurface safety valve, and a second position, where the control line pressure is diverted into the flow passage and the balance line pressure is diverted into a balance line jumper conduit.

Abstract: An actuator assembly for effective interventionless activation of a valve in wells of multilateral architecture. The assembly may be pressure actuated from an oilfield surface even in certain circumstances where another valve in another leg of the well has been opened in a manner compromising pressure control of the well. Due to the multi-stage nature of the actuator, pressure based activation remains viable as a result of supplemental and/or fail-safe modes of actuation, for example, where such pressure control becomes compromised.

Abstract: A valve arrangement including a housing having a port, a closure member defining a bore, the bore being of a smaller flow area than an adjoining flow area to produce a lower pressure in flowing fluid therein than pressure in fluid flowing in the adjoining flow area, the closure member being disposed within the housing and movable between a closed position and an open position, a volume defined between the closure member and the housing, an opening in the closure member extending from the volume to the bore of the closure member to convey fluid pressure generated in the bore of the closure member to the volume thereby creating a lower pressure in the volume thereby biasing the closure member into a closed position.

Abstract: A system for control using a hydraulic fluid includes a hydraulic control line for flowing the hydraulic fluid, a fluid line in fluid communication with the hydraulic control line, a flow controller configured to regulate a flow of the hydraulic fluid in the fluid line, and a piezoelectric device in fluid communication with the hydraulic control line and configured to actuate the flow controller upon receiving a selected flow of the hydraulic fluid.

Abstract: A casing having an inner diameter and an outer diameter, a packer positioned on a tool configured to expand across an annulus, and a pressure port positioned within a between the inner diameter and the outer diameter of the casing. The pressure port includes a first end being positioned on a lower annulus on a first side of the packer and second end being positioned on an upper annulus on a second side of the packer, wherein the pressure port is configured to create a pressure differential between the upper annulus and the lower annulus.

Abstract: A technique provides a simplified and cost-effective approach for deployment and operation of completion systems. The construction of the overall completion system and the deployment methodology provide an efficient approach for placement and operation of completion systems in a variety of wellbores. In many applications, the system and methodology may be used for sand control applications in which the completion equipment comprises sand control features, such as sand screens deployed along well zones.

Abstract: A system and method for vent gas combustion in storage tank for heavy oil production is provided. Auxiliary burners located are provided for combusting the well casing gas. A burner management system for controlling the auxiliary burners is provided which receives a gas pressure value and initiates the auxiliary burners based upon one or more threshold values when the gas pressure exceeds the one or more pressure values. An auxiliary exhaust stack may be collocated with a main exhaust stack of a tank heater for the storage tank.

Abstract: A downhole tool and method, of which the downhole tool includes a first sub defining a port extending radially therethrough, a second sub spaced apart from the first sub, and a housing connected with the first and second subs. A valve element is disposed at least partially within the housing, and is movable from a closed position to an open position. In the closed position, the valve element blocks fluid communication between a bore and an opening in the housing. When the valve element is in the open position, fluid communication between the bore and the opening is permitted. An actuation chamber is defined between the first sub, the housing, and the valve element, and is in fluid communication with the bore via a flow path that includes the port. A flow restrictor in the flow path is configured to slow fluid flow from the bore to the actuation chamber.

Abstract: An automatic drilling apparatus having a tool body, a motive device connected to the tool body, and a drill bit connected to the tool body. The apparatus also includes a setting tool connected to the body, at least one sensor disposed on the tool body, and a computer disposed in the tool body, wherein the computer is configured to actuate the motive device, the drill bit, the setting tool, and the at least one sensor.