Abstract: A rotary steerable drilling assembly for directional drilling includes a driveshaft rotatably disposed in a driveshaft housing, a bend adjustment assembly coupled to the driveshaft housing, a bearing mandrel coupled to the bend adjustment assembly, and a torque control assembly including a rotor configured to couple with a drill string, a stator assembly coupled to the downhole motor, and a torque control actuator assembly configured to control the amount of torque transmitted between the rotor and the stator assembly, wherein the bend adjustment assembly includes a first position providing a first deflection angle between a longitudinal axis of the driveshaft housing and a longitudinal axis of the bearing mandrel, wherein the bend adjustment assembly includes a second position providing a second deflection angle between the longitudinal axis of the driveshaft housing and the longitudinal axis of the bearing mandrel, the second deflection angle being different from the first deflection angle.

Abstract: A method of handling pipe segments during makeup and breakout of a drill string. The method uses a hydraulic circuit, which provides fluid to a motor or motors for translating a drill pipe segment. The drill pipe segment is supported by a carriage, which places the segment next to a drill string for addition thereto. Hydraulic pressure within the circuit is monitored to determine if a pressure fluctuation exists. If so, the translation speed is adjusted by modifying the hydraulic fluid flow to the motors. Sensors may be utilized to determine whether or not the system is in a “transition zone” and therefore ready for pressure monitoring for makeup and breakout functions.

Abstract: Provided, in one aspect, is a lateral locating assembly. The lateral locating assembly may include, in one aspect, a housing, as well as a piston positioned within the housing. The lateral locating assembly according to this aspect may further include a mandrel extending from a distal end of the housing, the mandrel configured to rotate and translate angularly in response to the piston moving from a first position to a second position, and a deflection tip coupled with a distal end of the mandrel, the deflection tip configured to rotate and angularly translate with the mandrel relative to the housing.

Abstract: An apparatus for drilling a secondary borehole includes a whipstock assembly configured to be deployed in a primary borehole, the whipstock assembly including a whipstock ramp, and a drilling assembly connected to a borehole string. The drilling assembly includes a drill bit connected to an articulated string portion having a plurality of connected sections configured to move laterally with respect to one another, and the articulated string portion is configured to be diverted by the whipstock ramp in a lateral direction to initiate drilling of a secondary borehole from the primary borehole.

Abstract: An apparatus for drilling curved and straight sections of a wellbore is disclosed that in one non-limiting embodiment includes a drilling assembly configured to include a drill bit at an end thereof that can be rotated by a drive in the drilling assembly and by the rotation of the drilling assembly, and wherein the drilling assembly includes: a deflection device that (i) tilts a section of the drilling assembly within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore by rotating the drill bit by the drive; and (ii) straightens the section of the drilling assembly when the drilling assembly is rotated to allow drilling of a straight section of the wellbore.

Abstract: In some aspects, the present disclosure includes systems and methods for rotatably coupling a bottom-hole assembly to a drilling shaft for use in subterranean drilling operations. In one embodiment, the methods of the present disclosure are suitable for underreaming a portion of a wellbore. The methods may comprise rotating a drilling shaft coupled to a drill bit about its axis to form a wellbore; engaging a first locking mechanism rotatably coupled to the drilling shaft with a second locking mechanism coupled to a housing to rotatably couple the drilling shaft and the housing; expanding an expandable reamer attached to the housing; and rotating the housing to widen at least a portion of the wellbore uphole from the drill bit. The bottom-hole may comprise one or more actuators that are selectively operable to engage the first and second locking mechanisms and expand the expandable reamer.

Abstract: A system, drilling assembly, and method to control adjustable pads for use in downhole directional drilling. The drilling assembly comprises a bent housing comprising an upper section, a lower section, a bend between the upper and lower sections, and a bore extending from the upper to lower sections. The drilling assembly also comprises a drill bit coupled to a lower end of the bent housing and a fluid-driven motor coupled to the bent housing and comprising a drive shaft coupled to the drill bit. The drilling assembly also employs an adjustable pad extendable and retractable from an exterior of the bent housing to engage and disengage the wellbore wall to adjust a drilling direction of the drill bit, and a fluid control system operable to control extension of the pad.

Abstract: A downhole tool having a mechanically adjustable bend angle from the surface and method for actuation of the tool. The tool includes a knuckled joint between upper and lower housing assemblies and tapered setting ring upon which the lower housing assembly bears. As the setting ring is rotated with respect to the upper housing assembly, the lower assembly is tilted. A spline sub for connection to a drill string is included, which, upon a certain weigh on bit, axially moves within the tool housing to engage the tapered setting ring and force shoes radially outward to engage the formation and hold the tool stationary. The drill string is then rotated to rotate the setting ring, and thereby alter the tool bend angle. Toggles hold the setting ring fixed to the upper housing to maintain a given bend angle during drilling operations.

Abstract: A whipstock assembly includes a whipstock providing a ramped surface, and a mill releasably coupled to the whipstock with a shear bolt and providing a mill profile. A tension arm is pivotably coupled to the whipstock and movable between a stowed position, where the tension arm is received within a cavity defined in the ramped surface, and an engaged position, where an engagement head of the tension arm mates with the mill profile to assume at least a portion of a tensile load assumed by the shear bolt.

Abstract: Underground drilling operation often requires connecting a drill tool (e.g., drill bit, backreamer, etc.) to a drill string. It is desirable to connect the drill tools to a drill string in a manner that facilitates quick and easy assembly and disassembly. Low torque coupling, commonly referred to as “torque-less” connection, can provide such functionality. The useful life and strength of such connections can be improved upon. The present disclosure provides a low torque coupling with improved strength and durability.

Abstract: A bending restrictor for a rigid but resilient rod-shaped intervention cable includes a series of pipe sections and articulation sleeves. Each pipe section includes a straight pipe piece with a spherical sector in either end. Each articulation sleeve includes two axially oppositely directed spherical-sector seats for holding about each pipe's spherical sector. The spherical sector seats are arranged in either ends of a central axial passage for the intervention cable. Two guide sheaves each with its sheave groove reside in the articulation sleeve's axial plan is laterally displaced relative to the middle of the axial passage so as for enveloping the axial passage for the intervention cable. The articulation sleeve is provided with two opposite axially directed and flattened pivot funnels, and each pivot funnel is provided with its narrower end in adjacent to each its spherical-sector seat.

Abstract: A steerable drill bit may be used to drill a lateral borehole from a primary wellbore. The steerable drill bit may be part of a bottomhole assembly that also includes a directional control system. A deflection member, such as a whipstock, may be anchored in the primary wellbore. When the bottomhole assembly approaches the deflection member, the directional control system may steer the steerable drill bit to reduce and potentially eliminate contact between the steerable drill bit and a ramped surface of the deflection member. By restricting contact between the deflection member and the steerable drill bit, cutting elements of the steerable drill bit may obtain an increase in cutting efficiency and/or effective life.

Abstract: The invention relates to a dynamic point-the-bit rotary steerable drilling tool and a measuring method thereof. The dynamic point-the-bit rotary steerable drilling tool comprises a rotary housing, a stabilized platform assembly, a hollow servo-motor assembly, a drilling fluid passage, an inner eccentric ring, an outer eccentric ring, a drilling bit shaft and a universal joint. The dynamic point-the-bit rotary steerable drilling tool also comprises a stabilized platform communication and power supply system which includes an instrument storehouse fixed at the upper end of the rotary housing, a main circuit board, an auxiliary circuit board mounted on the stabilized platform upper-end cover, an electromagnetic coupler primary-side, an electromagnetic coupler secondary winding and an electromagnetic coupler primary-side mounting plate fixed at the lower end of a coupler.

Abstract: A flexible milling assembly for milling an orifice through a well casing. The milling assembly can include a drive yoke, and a plurality of straight and split yoke assemblies—all linked together and to a cutter head with universal blocks that enable the components to pivot relative to each other. A string of joint tubing connected to a prime mover on the surface is used to lower the milling assembly into a well and supply the driving torque. A split shoe coupled to a guide tube is positioned within the well casing where the orifice is to be milled. The milling assembly is guided through a curved passage within the split shoe to bring the cutter head into contact with the well casing. A protector assembly can be provided to enclose and protect the milling assembly when it is tripping into and out of the well casing.

Abstract: Systems and methods for drilling a wellbore with a portion having a short radius of curvature. A drill assembly having a motor and a tubular housing. An actuator is at least partially disposed within the tubular housing and couples the motor to the tubular housing. The actuator is configured to selectively articulate the drill assembly between a straight configuration and a bent configuration. At least one torque anchor is fluidly-coupled to a trailing end of the drill assembly.

Abstract: A flexible milling assembly for milling an orifice through a well casing. The milling assembly can include a drive yoke, and a plurality of straight and split yoke assemblies—all linked together and to a cutter head with universal blocks that enable the components to pivot relative to each other. A string of joint tubing connected to a prime mover on the surface is used to lower the milling assembly into a well and supply the driving torque. A split shoe coupled to a guide tube is positioned within the well casing where the orifice is to be milled. The milling assembly is guided through a curved passage within the split shoe to bring the cutter head into contact with the well casing. A protector assembly can be provided to enclose and protect the milling assembly when it is tripping into and out of the well casing.

Abstract: A bottom hole assembly includes a drill string, a bit coupled to an end of the drill string, a rotary steerable system coupled to the drill string above the bit, a hydraulically actuated tool assembly coupled to the drill string above the rotary steerable system, and an electrically controlled tool coupled to the drill string above the hydraulically actuated tool assembly and electrically coupled to the rotary steerable system. A method includes running a bottom hole assembly downhole, the bottom hole assembly including a drill bit, a rotary steerable system, an electrically controlled tool, and a hydraulically actuated tool assembly disposed between the rotary steerable system and the electrically controlled tool. The method includes cutting a formation with the drill bit, actuating the hydraulically actuated tool assembly, and maintaining an electrical connection between the rotary steerable system and the electrically controlled tool during the running, the cutting, and the actuating.

Abstract: The present invention provides a system and method for directional drilling of a borehole in a formation along a predetermined trajectory.

Abstract: A method and apparatus for estimating the instantaneous rotational speed of a bottom hole assembly at the lower end of a drill string. In one embodiment, a method includes driving the drill string by a drilling mechanism at the upper end of the drill string. A fundamental frequency of stick-slip oscillations suffered by the drill string is estimated. Variations in a drive torque of the drilling mechanism are determined. Known torsional compliance of the drill string is combined with the variations in the drive torque. An output signal representing the instantaneous rotational speed is provided.

Abstract: A method, system and apparatus for steering a drill string employ, an eccentric steering device. The eccentric steering device may comprise an eccentric sleeve configured for mounting exterior to a portion of the drill string and permitting the drill string to rotate within the eccentric sleeve and a brake positioned to selectively cause rotation of the eccentric sleeve with the drill string. The eccentric steering device may further comprise one or more bearings positioned between the eccentric sleeve and the drill string.

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.

Abstract: A downhole motor for directional drilling includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing. In addition, the downhole motor includes a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing. The bearing mandrel has a first end directly connected to the driveshaft with a universal joint and a second end coupled to a drill bit. Further, the downhole motor includes an adjustment mandrel configured to adjust an acute deflection angle ? between the central axis of the bearing housing and the central axis of the driveshaft housing. The adjustment mandrel has a central axis coaxially aligned with the bearing housing, a first end coupled to the driveshaft housing, and a second end coupled to the bearing housing.

Abstract: A method and system for steering a rotary steerable tool in a borehole. A method includes rotating a deflection sleeve about a steerable shaft. A deflection ramp is aligned to deflect the shaft in a predetermined direction by the rotating. The deflection sleeve is axially displaced along the steerable shaft. The steerable shaft is deflected by the displacing.

Abstract: A directional drilling tool is provided, which comprises a first end (2) attachable to a drill string, and a second end (4) attachable to a drill bit. A swivel section (6) is provided intermediate the first and second ends (2,4) and has a first swivel member (18) non-rotatably attached to the first end (2) and a second swivel member (20) rotatably coupled to the first swivel member (18) and rotatable relative thereto about a first axis of rotation which is co-axial with a longitudinal axis (LI) of the tool. A first actuator is adapted to selectively rotate the second swivel member (20) about the first axis of rotation.

Abstract: A technique facilitates the drilling of deviated wellbores. A steerable drilling system is formed with a pair of components pivotably mounted with respect to each other. A removable strike ring is mounted to one of the steerable drilling system components and is positioned to engage a corresponding strike ring in a manner which limits the maximum pivot angle between the steerable drilling system components. By interchanging the removable strike ring with other removable strike rings, the maximum pivot angle can be adjusted in the field to accommodate drilling of a wider variety of deviated wellbores.

Abstract: A method and apparatus for estimating the instantaneous rotational speed of a bottom hole assembly at the lower end of a drill string. In one embodiment, a method includes driving the drill string by a drilling mechanism at the upper end of the drill string. A fundamental frequency of stick-slip oscillations suffered by the drill string is estimated. Variations in a drive torque of the drilling mechanism are determined. Known torsional compliance of the drill string is combined with the variations in the drive torque. An output signal representing the instantaneous rotational speed is provided.

Abstract: A rotary steerable tool has an inner mandrel having a longitudinal axis and an outer housing positioned along the inner mandrel. The outer housing rotates independently of the inner mandrel. The outer housing has an engagement member that moves axially relative to the outer housing and the inner mandrel between an extended position and a retracted position, and a transition surface having a slope relative to an outer surface of the outer housing. The engagement member moves along the transition surface between the extended position and the retracted position. In the engaged position, the engagement member extends outward from the outer housing to engage an inner surface of a well being drilled. An actuator selectively moves the engagement member along the transition surface from the retracted position to the extended position.

Abstract: A drilling system for directional drilling of a borehole includes a biasing mechanism having a pivot associated with a lower bearing assembly, an offset mechanism associated with an upper radial bearing assembly, and a toolface controller, whereby the angular relationship of a drill bit and its toolface angle may be actively managed.

Abstract: A technique utilizes a monolithic wellbore propagation system to facilitate the drilling of deviated wellbores. A steerable drilling assembly is formed with a monolithic structure having both a bit body section and a steering body section. The steering body section comprises a cavity sized to receive a control system within the monolithic structure. Addition of the control system enables operational control over the steerable drilling assembly to facilitate formation of a desired, deviated wellbore section.

Abstract: This invention relates to a steering component, to a steering assembly, and to a method of steering a drill bit in a borehole. The steering component is adapted for connection to a drill string, the drill string carrying a drill bit and a motor for rotating the drill bit. The steering component comprises: a rotatable driveshaft adapted for connection between the drill bit and the motor; a drive mechanism; and an offsetting component; the drive mechanism providing a rotatable connection between the drill string and the offsetting component whereby the drill string can rotate relative to the offsetting component. The drive mechanism is adapted to drive the offsetting component to rotate in an opposed direction to the driveshaft, so as to counter the rotation of the offsetting component which is induced by friction within the componentry as the driveshaft rotates. The steering component and method are likely to have their greatest utility in steering a drill bit during drilling for oil and gas.

Abstract: A drilling system has a drill string that is made up of tubular segments of coiled tubing joined together by connectors. The connectors can be selectively changed between locked and unlocked configurations. When in the unlocked configuration adjacent tubular segments rotate with respect to one another, and when in the locked configuration the tubular segments are rotationally affixed. The connectors include clutch members coupled to each tubular segment, that axially slide into a slot formed in an adjacent tubular segment to rotationally lock the adjacent segments. A Kelly bushing and rotary table rotate the drill string; and an injector head is used to insert the drill string through the Kelly bushing and rotary table and into a wellbore. While the drill string is inserted through the bushing and table, the connectors are set into the locked configuration so that all tubular segments from the rotary table downward are rotationally affixed.

Abstract: A steerable drilling system comprising a bottom hole assembly (18) including an upper section (22) and a steering section (24), a swivel (26) permitting adjustment of the orientation of an axis of the steering section (24) relative to that of the upper section (22), a downhole motor operative to drive the steering section (24) for rotation relative to the upper section (22), and a plurality of actuators (34) operable to control the orientation of the axis of the steering section (24) relative to that of the upper section (22), the (actuators 34) being mounted upon one of the steering section (24) and the upper section (22,) a high speed sliding contact being formed between the actuators (34) and the other of the steering section (24) and the upper section (22).

Abstract: A downhole drilling apparatus includes an assembly having a longitudinal axis, wherein an output shaft of the assembly extends axially through a housing. A bearing assembly has first and second races, wherein a first set of bearing elements are disposed at a first angle relative to a top surface of the first race and a second set of bearing elements are disposed at a second angle relative to a top surface of the second race. The output shaft extends from an outlet of the housing at the angle defined by the bore.

Abstract: This invention relates to a steering component, to a steering assembly, and to a method of steering a drill bit in a borehole. The steering component is adapted for connection to a drill string, the drill string carrying a drill bit and a motor for rotating the drill bit. The steering component comprises: a rotatable driveshaft adapted for connection between the drill bit and the motor; a drive mechanism; and an offsetting component; the drive mechanism providing a rotatable connection between the drill string and the offsetting component whereby the drill string can rotate relative to the offsetting component. The drive mechanism is adapted to drive the offsetting component to rotate in an opposed direction to the driveshaft, so as to counter the rotation of the offsetting component which is induced by friction within the componentry as the driveshaft rotates. The steering component and method are likely to have their greatest utility in steering a drill bit during drilling for oil and gas.

Abstract: A drilling assembly comprises a drill bit that includes a bit body intermediate a working face and a shank. An indenting member adapted to guide the drill bit protrudes from the working face. A flexible portion is disposed above the bit body.

Abstract: An apparatus for drilling a wellbore may include a first section, a second section, and a third section, all of which are rotatably interconnected with pivot bearings and positioned along a drill string. The second section and the third section may be configured to form a controllable bend angle in the drill string. The first section, the second section, and the third section may be configured as sleeves that surround a portion of the drill string. One or more sections may include locking pads that selectively engage a wall of the wellbore. A hydraulic locking device for controlling a direction of rotation of the second section may include one or more brake elements and a reverse spinning sleeve. A first brake element may be used engage the reverse spinning sleeve and a second brake element may be used to engage a drive shaft.

Abstract: A technique facilitates the drilling of deviated wellbores. A steerable drilling system is formed with a pair of components pivotably mounted with respect to each other. A removable strike ring is mounted to one of the steerable drilling system components and is positioned to engage a corresponding strike ring in a manner which limits the maximum pivot angle between the steerable drilling system components. By interchanging the removable strike ring with other removable strike rings, the maximum pivot angle can be adjusted in the field to accommodate drilling of a wider variety of deviated wellbores.

Abstract: A drilling apparatus includes an upper drill string, a lower drill string including a rotary drilling motor, an orientable rotatable connection between the drill strings, a reactive torque control device associated with the orientable rotatable connection, an orientation sensing device for providing a sensed actual orientation of the lower drill string, and a feedback control system configured to actuate the control device in response to the sensed actual orientation to achieve a target orientation of the lower drill string. A drilling method includes actuating the control device to prevent relative rotation of the drill strings, providing a sensed actual orientation of the lower drill string, comparing the sensed actual orientation with a target orientation of the lower drill string, actuating the control device to allow the lower drill string to rotate to provide the target orientation, and actuating the control device to prevent relative rotation of the drill strings.

Abstract: A drill string section for directional drilling includes an outer casing which encases an adjustment mechanism for adjusting drilling direction and angular deflection during drilling. The adjustment mechanism has an outer shaft that is rotatably arranged relative to the outer casing and is configured with an axial eccentric first bore having a first bore axis that is parallel to the centre axis.

Abstract: A downhole steering system comprises a first full gauge stabilizer 34, a bias unit 28, a universal joint 26, and a second full gauge stabiliser 22, the bias unit 28 and universal joint 26 being located between the first and second full gauge stabilizers 34, 22. The system further comprises a drill bit 10 and a fluid powered downhole motor 14, the motor being located, at least partially, between the drill bit 10 and the second stabilizer 22.

Abstract: This invention relates to a steering component, to a steering assembly, and to a method of steering a drill bit in a borehole. The steering component is adapted for connection to a drill string, the drill string carrying a drill bit and a motor for rotating the drill bit. The steering component comprises: a rotatable driveshaft adapted for connection between the drill bit and the motor; a drive mechanism; and an offsetting component; the drive mechanism providing a rotatable connection between the drill string and the offsetting component whereby the drill string can rotate relative to the offsetting component. The drive mechanism is adapted to drive the offsetting component to rotate in an opposed direction to the driveshaft, so as to counter the rotation of the offsetting component which is induced by friction within the componentry as the driveshaft rotates. The steering component and method are likely to have their greatest utility in steering a drill bit during drilling for oil and gas.

Abstract: A method for correcting for tool face offset in directional drilling components, namely between a directional sensor reference point and a high side of a bent sub. Graduated markings applied on an outer surface of a UBHO sub containing the directional sensor and a reference marking on drill pipe indicating high side of the bent sub, or alternatively graduated markings applied to drill pipe relative to the high side of the bent sub and a reference marking on the outer surface of the UBHO, are together utilized to determine the tool face offset, which is then provided to a software program to permit the software programme to then indicate a correct bent sub angular orientation to the directional drilling operator at surface. Bottom hole components utilizing graduated markings on one of such bottom hole components and having a reference marking on the other of the components, are also disclosed.

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: 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 drive connection for a downhole drilling motor includes a tubular outer housing with an inner mandrel. The outer housing has a motor end, a bit end and defines an interior bore. An angular offset is provided toward the bit end of the outer housing. The inner mandrel, positioned within the interior bore of the outer housing, includes a motor end section, a bit end section and an intermediate section connecting the motor end section and the bit end section. The intermediate section has an upper articulating engagement that is coupled to rotate with the motor end section and a lower articulating engagement that is coupled to rotate with the bit end section. The motor end section, intermediate section and bit end section rotate together, with the upper articulating engagement and the lower articulating engagement accommodating rotation that is offset due to the angular offset.

Abstract: A technique utilizes a monolithic wellbore propagation system to facilitate the drilling of deviated wellbores. A steerable drilling assembly is formed with a monolithic structure having both a bit body section and a steering body section. The steering body section comprises a cavity sized to receive a control system within the monolithic structure. Addition of the control system enables operational control over the steerable drilling assembly to facilitate formation of a desired, deviated wellbore section.

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.

Abstract: A method for forming lateral boreholes from an existing parent wellbore is provided. The wellbore has been completed with a string of production casing. The method generally comprises providing a downhole tool assembly having a whipstock. The method also includes running the assembly down into the parent wellbore. A force is applied to the assembly to cause the whipstock to rotate within the wellbore into an operating position. In this position, a curved face of the whipstock forms a bend-radius substantially across the inner diameter of the casing. A jetting hose is run into the wellbore. Upon contact with the curved face of the whipstock, the jetting hose is re-directed through a window in the production casing. Hydraulic fluid is injected under pressure through the hose to provide hydraulic jetting. The hose is directed through the window and into the formation to create a lateral borehole extending many feet outwardly into a subsurface formation.

Abstract: A drill rod is disclosed. The drill rod includes a casing assembly defining a length that extends axially between a first end and an opposite second end of the drill rod, and a drive shaft rotatably mounted within the casing assembly. The drive shaft extends axially along the drill rod generally from the first end of the casing assembly to the second end of the casing assembly. The drill rod also includes latching pins at the first end of the drill rod and latching pin receivers at the second end of the drill rod. The drill rod further includes latches provided adjacent the latching pin receivers. The latches are movable between latching and non-latching positions. The latches move along an orientation of movement then the latches between the latching and non-latching positions. The drill rod may also include biasing structures that apply retention forces to the latches for retaining the latches in the non-latching position.

Abstract: A method for forming multiple lateral boreholes from an existing wellbore is provided. The wellbore has been completed with a string of production casing. The wellbore may have a slimhole region having an inner diameter that is less than the inner diameter of the production casing. The method generally comprises providing a downhole apparatus having a whipstock. The whipstock may be a single piece tool that rotates into position below the slimhole region, or it may be a two piece tool comprising a top whipstock member and a separate bottom whipstock member. The whipstock has a curved face. The method also includes running the apparatus down into the parent wellbore. A force is applied to the apparatus to cause the whipstock to rotate within the wellbore into an operating position. In this position, the curved face of the whipstock forms a bend-radius that allows the jetting hose to bend across the entire inner diameter of the production casing. A jetting hose is run into the wellbore.