Abstract: A method of steering a drilling operation of a well using acoustic measurements. The method includes obtaining, using a central processing unit (CPU), a clean-wet matrix line for the well, where the clean-wet matrix line includes a number of normal compressional values, obtaining, using the CPU, the acoustic measurements from at least one logging while drilling tool at a current depth of the drilling operation, where the acoustic measurements include a compressional to shear velocity ratio and a delta-T compressional measurement, and determining, using the CPU, a current phase of the drilling operation by comparing the acoustic measurements to the clean-wet matrix line. The method further includes, in response to determining that the current phase is not a target phase, generating an updated well trajectory for steering the drilling operation toward the target phase and adjusting the drilling operation using the updated well trajectory.

Abstract: The present invention relates to an innovative wellbore concept, which gives experts a new alternative enabling them to analyse the economic viability of a deposit. The new structural arrangement for oil wells involves the utilisation of equipment that is already available at the wells (of dry or wet completion), and the exploitation of a remote neighbouring field by mechanical and hydraulic interconnection. The implementation method uses already known drilling tools and techniques, but renders their applicability advantageous, since it ensures production from deposits or wells that are not considered viable, by using resources that are already available and in operation.

Abstract: The present invention recites a method and apparatus, wherein said methods and apparatus comprises an actuator comprising a first plate, a pocket extending through the first plate, the pocket in fluid communication with a pressurized fluid source and a second plate coupled to a component that is to be actuated, wherein the first plate, the second plate, and the pocket are dimensioned such that when a pressurized fluid is discharged through the pocket, the velocity of the fluid through a gap between the first plate and the second plate creates a pressure drop sufficient to pull the second plate toward the first plate.

Abstract: The present invention recites a method, system and apparatus, wherein said method, system and apparatus comprises a gauge pad for a rotary component received within a borehole, the gauge pad comprising an exterior surface dimensioned for rotation in close proximity to the borehole, a pocket extending through the exterior surface, the pocket in fluid communication with a pressurized fluid source, and wherein the exterior surface is dimensioned such that when a pressurized fluid is discharged through the pocket, the velocity of the fluid through a gap between the exterior surface and borehole creates a pressure drop sufficient to pull the rotary component toward the gauge pad.

Abstract: A system for automating service operations at a well includes a service rig having at least one input device, an engine connected to an engine electronic control unit having a engine controller area network, a plurality of crown sheeves, a cable, an output device, a communication infrastructure, and at least one of a computer and an operator station; at least one remote server in electronic communication with the communication infrastructure; and a web portal in electronic communication with the at least one remote server.

Abstract: Various embodiments are directed to a method of switching horizontal directional drilling procedures during bore path turning. Such methods can include identifying a hierarchal arrangement of a plurality of different boring procedures utilizing different boring techniques, the hierarchy arrangement representing boring procedures of increasing ability to bore through harder soil while changing a trajectory of a boring tool. Such methods can further include boring a first leg of a curved bore path using a boring tool connected to a drill rig by a drill string, the first leg being bored using a first boring procedure of the plurality of different boring procedures. Such methods can further include monitoring a plurality of boring parameters during boring of the first leg, the plurality of boring parameters comprising: torsional pressure of the drill string, rotational travel of the drill string, hydraulic pressure, and axial displacement.

Abstract: A system and method for surface steerable drilling are provided. In one example, the system receives feedback information from a drilling rig and calculates an estimated position of a drill bit in a formation based on the feedback information. The system compares the estimated position to a desired position along a planned path of a borehole. The system calculates multiple solutions if the comparison indicates that the estimated position is outside a defined margin of error relative to the desired position. Each solution defines a path from the estimated position to the planned path. The system calculates a cost of each solution and selects one of the solutions based at least partly on the cost. The system produces control information representing the selected solution and outputs the control information for the drilling rig.

Abstract: A system and methodology provide improved control over the directional drilling of a wellbore. A rotational valve is mounted within a drill collar of a rotary steerable system to enable selective actuation of one or more steering pads on the drill collar via an actuating fluid. The rotational valve is controlled via a motor and designed to provide enhanced control over the flow of actuating fluid to the steering pads.

Abstract: A system and methodology provide improved control over the directional drilling of a wellbore while enabling additional functionality. A rotational valve is mounted within a drill collar of a rotary steerable system to control flow of actuating fluid to one or more steering pads which are selectively moved in a lateral direction with respect to the rotary steerable system. The rotational valve also is controlled to carry out at least one additional function while controlling the direction of drilling.

Abstract: A system and methodology provide improved control over the directional drilling of a wellbore. A rotational valve is mounted within a drill collar of a rotary steerable system to control flow of actuating fluid to one or more steering pads which are selectively moved in a lateral direction with respect to the rotary steerable system. The rotational valve is designed to provide enhanced control over the flow of actuating fluid to the steering pads to facilitate drilling of straight sections of wellbore and deviated or non-linear sections wellbore.

Abstract: A system and method for enabling longitudinal and radial drilling in a wellbore is described. The system and method enable an operator to perforate the casing of a wellbore with an under-reamer at the end of a drill string and, without removing the drill string from the wellbore, initiate and complete lateral jetting of the wellbore into the surrounding formation. The system utilizes a perforation tool having a ball seat, which upon seating a drop ball in the ball seat enables the perforation tool to move from a closed position to an open position thereby allowing access to the formation using a jetting tool. Prior to seating the drop ball, an under-reaming operation may be performed using a hydraulic pressure activated under-reaming tool.

Abstract: A long distance power transfer coupler for wellbore applications system uses two or more wireless modules, each wireless module comprises a self-resonant coil, to transmit energy within a wellbore. The second, and potentially subsequent, wireless modules receive radiant electromagnetic energy from a nearby neighbor which the self-resonant coil converts to usable electromagnetic energy which may be used for power, data communications, or a combination thereof. A first module may be deployed at a predetermined position in the wellbore; a cable attached to a second length of tubing; and one or more second modules attached to the tubing and coupled inductively to a resistive load. The tubing and second module or modules are deployed downhole and electromagnetic energy transmitted wirelessly between the first module and the second module. Modules may be deployed in a completion string.

Abstract: A system and method facilitate directional drilling. The technique employs an orienting tool which may be connected into a coiled tubing drilling system to selectively orient a drilling assembly. The orienting tool is able to cause relative rotation of an outer housing to orientate a tool face. The relative rotation is facilitated by utilizing floating members, such as a floating piston and a floating nut, in the internal orientation assembly. The floating member or members are decoupled in a radial direction to better facilitate the relative rotation of the housing with respect to components of the internal orientation assembly.

Abstract: A horizontal direction drilling system comprises a power pack coupled to a source of compressed air and a water reservoir and forms a mixture of compressed air, water, and oil. The horizontal direction drilling system further comprises a steerable horizontal drill. The steerable horizontal drill includes an air powered reciprocating hammer, and a drill head. The steerable horizontal drill receives the mixture to power the reciprocating hammer. The drill head includes a drill face and the mixture exits the steerable horizontal drill through the drill face.

Abstract: A tracking receiver system is used to track the progress of a downhole tool along a subsurface path having a desired grade. The tracking receiver system is adapted to detect a reference line originating from a reference line receiver and to determine the position of the downhole tool along a desired subsurface path relative to the reference line. In an alternative embodiment the tracking receiver system may comprise a global positioning satellite system to provide information used to determine the position of the downhole tool relative to the desired subsurface path.

Abstract: A drilling system, comprising a non-rotating conveyance system; a tool connected to the non-rotating conveyance system and including anchors by which the tool can be anchored in position when located in a borehole; a drill bit connected to the tool; a motor for rotating the drill bit; and a directional control system interposed between the tool and the drill bit; wherein, in use, whit the drilling system located in a borehole, the directional control system can be operates so as to displace the drill bit away from the axis of the borehole.

Abstract: A drill bit includes a bit body having a face on which two different types of cutting elements are disposed, the first type being cutting elements suitable for drilling at least one subterranean formation and the second type being cutting elements suitable for drilling through a casing bit disposed at an end of a casing or liner string and cementing equipment or other components, if such are disposed within the casing or liner string, as well as cement inside as well as exterior to the casing or liner string. The second type of cutting elements exhibits a relatively greater exposure than the first type of cutting elements, so as to engage the interior of the casing bit and, if present, cementing equipment components and cement to drill therethrough, after which the second type of cutting elements quickly wears upon engagement with the subterranean formation material exterior to the casing bit, and the first type of cutting elements continues to drill the subterranean formation.

Abstract: A method of milling a window through a casing in a primary well bore and drilling an enlarged sidetracked well bore comprises running into the primary well bore a drilling assembly comprising at least one cutting apparatus adapted to drill an enlarged borehole, milling a window through the casing, and drilling the enlarged sidetracked well bore, wherein the milling and drilling steps are performed in one trip into the primary well bore. A drilling assembly comprises at least one cutting apparatus operable to drill an enlarged borehole, wherein the drilling assembly is operable to mill a window through a casing in a primary well bore and drill an enlarged sidetracked well bore through the window in one trip into the primary well bore.

Abstract: Disclosed herein are, among other things, piston steering devices and methods for use of piston devices. One aspect as disclosed herein provides a ball piston device including: a sleeve in fluid communication with a fluid source and a ball received within the sleeve. The ball is movable within the sleeve from a recessed position and an extended position.

Abstract: This invention relates to a steerable drill bit arrangement, in particular for the use in drilling boreholes for oil and gas extraction. According to the invention there is provided a steerable drill bit arrangement comprising a drill bit, a steering component and a stabilizer, the steering component being adapted to provide a steering force which in use can drive the drill bit along a non-linear path, the stabilizer being located between the drill bit and the steering component and in use providing a fulcrum for the steering force provided by the steering component, the position of the fulcrum provided by the stabilizer being adjustable relative to the drill bit and the steering component. In use, the position of the fulcrum can be adjusted to vary the maximum curvature of the borehole and to suit the rock type(s) being drilled.

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

Abstract: The present invention provides for pulsed powered drilling apparatuses and methods. A drilling apparatus is provided comprising a bit having one or more sets of electrodes through which a pulsed voltage is passed through a mineral substrate to create a crushing or drilling action. The electrocrushing drilling process may have, but does not require, rotation of the bit. The electrocrushing drilling process is capable of excavating the hole out beyond the edges of the bit with or without the need of mechanical teeth.

Abstract: A drill bit comprising: a cutting section comprising gage cutters, wherein in the cutting section is a first end of the bit, and wherein the cutting section has a full gage diameter; a heel section comprising a blade, wherein the heel section is at an end of the drill bit opposite the cutting section, and wherein a diameter of the heel section is a full gage diameter, wherein the blade has a high spiral around the drill bit; and a clearance section between the cutting and heel sections, wherein the clearance section comprises a diameter less than full gage, and wherein clearance section extends from the gage cutters of the cutting section to the blade of the heel section.

Abstract: A system and method is provided for drilling a wellbore using a rotary drill bit with a bit body having a plurality of mechanical cutters to cut away formation material as the wellbore is formed; and a directed energy mechanism to direct energy into the formation. The energy from the directed energy mechanism is used to enhance the cutting of the mechanical cutters by fracturing surrounding material to facilitate drilling in the direction of the directed energy.

Abstract: A system and method for downhole measurement for use with drill strings to reduce the borehole gap with respect to sensors carried by the drill string. In one embodiment, the sensors are mounted on a surface of the directional drilling hinged pad that comes in contact with the borehole wall. The hinged pad is pressed against the borehole wall as contact is made with the wall, thereby keeping the sensors at a minimum gap with respect to the wall. In another embodiment, the hinged pad is not used for directional drilling. Therefore the hinged pad is extended outward to the wall with the minimum necessary amount of force. Activation of the hinged pad can be initiated, for example, by flow of mud in the annulus of the string or through a user-provided command. The sensors can include resistivity, density, neutron, electromagnetic, acoustic, seismic, and NMR measurement sensors.

Abstract: A drill bit direction system and method is disclosed that modifies or biases the stochastic movement of the drill bit and/or stochastic interactions between the drill bit and an inner-wall of a borehole being drilled by a drilling system to change the direction of drilling of the drilling system. The direction of the drill bit is monitored to determine if the direction happens to align in some way with a preferred direction. If the direction isn't close enough to a preferred direction, a biasing mechanism modifies the stochastic movement in an attempt to modify the direction closer to the preferred direction. Any of a number of biasing mechanisms can be used. Some embodiments can resort to conventional steering mechanisms to supplement the biasing mechanism.

Abstract: Embodiments include ball piston steering devices and methods for use of ball piston devices. In one aspect a ball piston steering device includes a sleeve in fluid communication with a fluid source and a ball received within the sleeve. The ball is movable within the sleeve between a recessed position and an extended position.

Abstract: In one aspect of the present invention, a steering assembly for downhole directional drilling comprises an outer bit comprising a bore and an outer cutting area and in inner bit comprising an inner cutting area and connected to a shaft that is disposed within the bore. At least one biasing mechanism is disposed around the shaft. At least one fluid channel is disposed within the outer bit and redirects fluid to the at least one biasing mechanism causing the at least one biasing mechanism to push the shaft and alter an axis of the inner bit with respect to an axis of the outer bit.

Abstract: A method of directional drilling includes forming first and second pits on corresponding first and second sides of a barrier, forming a pilot bore from the first pit to the second pit, enlarging the pilot bore to a final bore, and extending a cable through the final bore between the first and second pits by attaching the cable to a remote controlled vehicle and driving the remote controlled vehicle through the final bore from one of the pits to the other pit. The method also includes pulling a pipeline through the final bore using the cable.

Abstract: This disclosure relates in general to a method and a system for directionally drilling a borehole with a rotary drilling system. More specifically, but not by way of limitation, methods and system provide for controlling motion of the rotary drilling system in the borehole when a side force is applied to the drilling system to bias or focus the motion so that the drilling system directionally drills the borehole through an earth formation. In certain aspects, side cutting of a sidewall of the borehole by a drill bit under an applied side force is controlled by a geostationary element to provide for directional side cutting and, as a result, directional drilling of the borehole through the earth formation. In other aspects, a non-concentrically coupled gauge pad assembly may rotate with the drilling system and bias or focus the applied side force.

Abstract: In one aspect of the present invention, a steering assembly for downhole directional drilling comprises a drill bit comprising a cutting portion and an outer diameter. A steering ring disposed around the outer diameter, and at least one biasing mechanism disposed intermediate the outer diameter and the steering ring. The at least one biasing mechanism is configured to move the steering ring with respect to the outer diameter.

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

Abstract: The present invention relates to systems and methods for controlling downhole motors. One aspect of the invention provides a valve-controlled downhole motor including: a downhole motor and a spool valve. The downhole motor includes a sealed chamber having a first port and a second port, a stator received within the sealed chamber, and a rotor received within the stator. The spool valve includes a barrel and a spool received within the barrel. The barrel includes an inlet port, an exhaust port, a first feed port, a second feed port, a first return port, and a second return port. The inlet port is located in proximity to the first feed port and second port. The exhaust port is located in proximity to the first return port and the second return port. The spool includes a first gland and a second gland.

Abstract: A tilted drive sub is disclosed with a center line of the internal diameter (ID) offset at an angle from the center line of the outer diameter (OD) starting at a point near to a top end of the tilted drive sub. This results in the ID being at an angle to the OD, with the OD of the tilted drive sub remaining straight. The offset ID has the same threads of a mud motor without a tilted drive sub. The tilted drive sub replaces the outer bearing housing of a normal performance mud motor.

Abstract: The present invention provides a directional drilling apparatus and method for use in drilling bore holes. The apparatus comprises a plurality of movably mounted cutting elements, wherein the cutting elements are movable between radially retracted and extended cutting positions. A rotary valve is provided for synchronizing the movement of the cutting elements between their respective extended and retracted positions. Control of the directional drilling system is affected by synchronized movement of the cutting elements from an inner to an outer radial position in accordance with the angular position of the drill bit. Means are provided for directing high pressure cutting fluid to the region between the cutting elements and the rotatable body to prevent the accumulation of debris that could prevent movement of the cutting elements. The cutting elements enlarge the bore hole formed by the drill bit, so that the cutting elements continuously engage the wall of the bore hole.

Abstract: A downhole tool assembly for cutting laterally into an earthen formation from a wellbore. The downhole tool assembly includes a cutting head assembly and a flexible tubular shaft member, wherein the cutting head assembly includes a rotatable nozzle and a cutting head sized and configured to cut laterally into the earthen formation.

Abstract: A downhole tool assembly for cutting laterally into an earthen formation from a wellbore. The downhole tool assembly includes a cutting head assembly and a flexible tubular member, wherein the cutting head assembly includes a rotatable nozzle and a cutting head sized and configured to cut laterally into the earthen formation. The downhole tool assembly may be guided through a channel defined by a guide assembly and positioned such that the cutting head is proximate the portion of the earthen formation to be laterally cut. A rotational source may be operatively connected and in fluid communication with the conduit and flexible tubular member, whereby torque generated by the rotational source is translated by the flexible tubular member to the cutting head, causing the cutting head to rotate and cut the earthen formation.

Abstract: A cutting device for downhole operations includes a first cutting structure, and a second cutting structure, wherein at least the second cutting structure is selectively presentable for operation. A method of performing a downhole cutting operation comprises running into a well bore a cutting device including a plurality of cutting structures, performing a first cutting operation with a first cutting structure of the cutting device, moving the first cutting structure to selectively present a second cutting structure of the cutting device, and performing a second cutting operation with at least the second cutting structure. The method may further include aligning movable cutting structures of the cutting device to allow the second cutting structure to be selectively presented.

Abstract: A system and method for drilling a wellbore along a desired well path is disclosed. The system and method employed a bearing housing which may be connected into a bottom hole assembly to facilitate drilling of deviated wellbore sections. The bearing housing has an internal bore with an axis that can be positioned to form a non-zero angle with the central or longitudinal axis of the bearing housing. The internal bore is designed to rotatably receive a drill bit shaft such that a drill bit is oriented at a desired angle with respect to the bearing housing. Alternatively, the internal bore may be positioned in a sleeve which is received in the bearing housing.

Abstract: A wireline apparatus for deep well measurements in a borehole being drilled includes a drill string having multiple drill pipe sections connected end-to-end, with at least one of the drill pipe sections being electrically conductive and isolated to provide an electrode section. A nonmagnetic drill pipe section is connected in the drill string below said electrode section, and a hydraulic motor having a rotatable drill bit carrying a drill bit instrument sub having a magnetic field sensing instrument package is connected to a lowermost end of the drill string. A wireline locatable within said drill string incorporates an electrode locatable within the drill pipe electrode section, and carries at its distal end a wireline instrument package that is locatable within the nonmagnetic drill pipe section to receive data representing magnetic field data from the magnetic field sensing instrument package.

Abstract: A directional drilling apparatus include a first cutter that substantially cuts a wellbore bottom along a first axis and a second cutter that cuts the wellbore bottom along a second axis different from the first axis. The second cutter may extend an adjustable amount out of the first cutter. In another embodiment, a pilot string may connect the second cutter to the first cutter.

Abstract: A directional drilling system and method are provided for directional drilling a borehole by continuous rotating of the drill string in combination with an arrangement of drilling motor assemblies at the lower end of the drill string to effect drilling along a curved path and a substantially straight path. A first drilling motor assembly is coupled to a drill bit and operable to rotate the drill bit to effect drilling of the borehole. A second drilling motor assembly, positioned on the drill string above the first drilling motor assembly, is operable to rotate the first drilling motor assembly in a direction opposite the direction of rotation imparted to the drill string from the surface and to the drill bit by the first drilling motor assembly.

Abstract: A method of forming a supported subterranean well bore in which, in one disclosed embodiment, a first drill bit is mounted on a first string of casing tubulars via a steerable tool, and the drill bit is used to form a first bore. Upon reaching the required depth the casing string is cemented in place to support the formed bore and a second drill bit is mounted on a second casing string and is inserted into the first casing string. The second drill bit is used to drill through the wall of the first casing string and proceed to form a second, deeper bore. Once the second drill bit has reached the required depth, the second casing string is cemented in place to support the second bore.

Abstract: A system and a method for directional drilling may generate a model of steering behavior which may be used to estimate a position and an orientation of the drill bit during directional drilling. The estimated position and the estimated orientation may be compared to the well plan to determine desired drilling behavior, and the desired drilling behavior may be used to determine a recommended toolface orientation and/or recommended intervals of sliding and rotating to conform the directional drilling to the well plan.

Abstract: A rotary steerable apparatus is provided having an actuator for pushing the bit or pointing the bit that includes a shape memory alloy. An elongated form of the alloy, such as a wire or rod, is employed in a mechanism that applies force in a direction transverse to the wellbore in response to a change in length of the alloy. Temperature of the alloy is controlled to change shape and produce the desired force on pads for operating the apparatus. The apparatus may be used with downhole power generation and control electronics to steer a bit, either in response to signals from the surface or from downhole instruments.

Abstract: A bottom-hole assembly for directional drilling incorporates a torque generator with a drive shaft connected to a drill string. The torque generator generates a torque that counters a reactive torque when a drill bit of the bottom-hole assembly is driven. When the drill string is rotated at a static drive speed, a drill tool face of the bottom-hole assembly is stabilized to drill a nonlinear bore segment. When the drill string is rotated at a rotational speed other than the static drive speed the bottom-hole assembly is rotated to drill a linear bore segment.

Abstract: A wellbore is formed by using an apparatus that may include a shaft having an end portion, a drill bit body tiltable about the end portion, and at least one actuator configured to apply a tilting force to the drill bit body.

Abstract: A drill bit system for a drilling assembly is disclosed. The drill bit system may include a chassis, a head, and one or more compliantly coupled gauge pads. The head may include a first plurality of cutters coupled with an end of the head, and the head may be coupled with chassis. The one or more gauge pads may include a second plurality of cutters, and the one or more gauge pads may be movably coupled with the chassis.

Abstract: A method of drilling a subterranean formation includes positioning a drill string in a well bore in the subterranean formation. The drill string includes a hammer bit, a bend in a housing of the drill string, and a guidance system that determines inclination and azimuth of at least a portion of the drill string in the well bore. Once positioned in the well bore, the hammer bit is caused to repeatedly strike the end of the well bore while rotating about an axis of the hammer bit thereby drilling the subterranean formation and forming a new length of the well bore in the subterranean formation. The orientation of the bend of the drill string in the well bore is controlled based on the determined inclination and azimuth such that the hammer bit drills the new length of the well bore substantially horizontally in the subterranean formation.

Abstract: Disclosed herein is a system for steering the direction of a borehole advanced by cutting action of a rotary drill bit by periodically varying action of a drill bit while continuously rotating a drill string to which the drill bit is operationally attached. The steering system can include a bit perturbation device cooperating with a bent housing subsection and operationally connected to the drill string and to the drill bit. Drill bit action can be varied by periodically varying the rotation speed and/or rate of penetration of the drill bit. Periodic drill bit action results in preferential cutting of material from a predetermined arc of the borehole wall which, in turn, results in borehole deviation. Action of the drill bit can be varied independently of the rotation rate of the drill string.