Abstract: The present disclosure discloses a drilling machine. The drilling machine may include a base, a mast arranged on the base, an iron roughneck, a drill floor mechanical arm, a top drive arranged on the mast, a pipe racker on a finger board, a power finger board, a power catwalk arranged on the ground, and an elevator arranged on the top drive. The drill machine and a corresponding tripping out and tripping in method may be used to vertically transport a stand between a well center and a region of at least one pipe setback efficiently, which may improve the efficiency of tripping out and tripping in, and reduce the risk of accidents in the well. In addition, the present disclosure provides a corresponding method for offline connecting and disconnecting stands during a drilling operation, which may reduce a preparation time during the drilling, improve the drilling efficiency, and reduce the cost of oilfield development.

Abstract: A method and apparatus for patching damaged areas in a well includes a top and a bottom patching section which include an anchor/sealing member for securing the apparatus within the well. One or more extension patch sections are connected between the top and bottom patch sections. The top and bottom patch elements are placed above and below the damaged area to isolate the damaged area from the exterior flow portion of the well.

Abstract: A gripper assembly for handling continuous rod. The gripper assembly may include a gripper face with a gripper profile forming a surface in the gripper face and a texture on a portion of the surface. The texture has a plurality of ridges having a yield strength sufficient to transfer a shear force to the gripper assembly at least as large as a weight of a continuous rod.

Abstract: A method of conducting subterranean drilling operations comprising guiding a tubular with a first guide arranged in a first configuration; coupling an umbilical line to the tubular with an engagement element; guiding the tubular with a second guide; arranging the first guide to a second configuration to permit longitudinal passage of the engagement element past the first guide; and arranging the first guide to the first configuration after the engagement element is past the first guide. A system for conducting subterranean operations comprising a first guide and a second guide disposed at different vertical elevations, wherein the first and second guides are adapted to provide continuous support to a tubular in a lateral direction when the tubular is coupled with an umbilical line.

Abstract: A technique facilitates use of a frac diverter instead of a frac plug in a variety of fracturing operations. The frac diverter has a simpler and less expensive construction. Although the frac diverter may not form a seal with the surrounding casing in some applications, the frac diverter is able to sufficiently restrict flow of fracturing fluid to enable a successful fracturing operation. The frac diverter may comprise arrangements of at least one cone, at least one slip ring, and at least one corresponding sub which work in cooperation with a flow restricting element. The flow restricting element may comprise various types of rings, e.g. sealing element rings, able to sufficiently restrict flow of fracturing fluid past the frac diverter.

Abstract: A tool circulates drilling fluid through and rotates a pipe string while making up or breaking out a stand of pipe. The tool includes a clad configured to grip and seal around the RCCT sub. The clad includes a body portion, an inner ring configured to selectively rotate independently, an outer ring configured to be stationary with respect to the inner ring, the outer ring having at least two annular protrusions, a first arm configured to engage with a first annular protrusion, a second arm configured to engage with a second annular protrusion, and a stinger configured to latch into the at least one side entry port and allow the sub and the drill pipe string to rotate independent of the clad. The clad is configured to avoid or prevent stuck pipe incidents.

Abstract: A downhole tool for use in a downhole drill string is provided. The downhole tool includes a rotor movably coupled within a stator, and a drive shaft movably coupled within a bearing housing. The drive shaft has a first end coupled with the rotor and a second end coupled with a drill bit. Bearing assemblies interfaces engagement between the drive shaft and the bearing housing, including polycrystalline diamond elements, each with an engagement surface, and an opposing engagement surface of a non-superhard metal.

Abstract: An apparatus that is usable with a well includes a tubular assembly and an expansion tool. The tubular assembly has a radially contracted state and includes a restriction. The restriction is adapted to catch an object that is deployed into the well to form a fluid barrier when caught by the restriction. The expansion tool is deployed downhole with the tubular assembly inside a tubing string. The expansion tool is adapted to deform the tubular assembly to anchor the tubular assembly to the tubing string.

Abstract: This disclosure provides a completion tool that uses a rolling seal to actuate a flow valve or replace a piston in a down hole tool. The rolling seal is located in a fluid chamber of the completion tool and divides the fluid chamber into first and second smaller fluid chambers and fluidly seals the first smaller fluid chamber from the second smaller fluid chamber. The rolling seal responds to a fluid pressure within the fluid chamber that causes the closed end of the rolling seal to invert thereby transferring fluid pressure between the first and second fluid chambers, which actuates a flow valve actuation assembly.

Abstract: The present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, more particularly, to an improved liner hanger system. A downhole expandable liner hanger positionable in a subterranean wellbore may comprise an expansion element. The expansion element may comprise a tubular body. The expansion element may comprise one or more annular seals bonded to the tubular body. The expansion element may comprise a first spike extending from the tubular body. The expansion element may comprise a second spike extending from the tubular body. The downhole expandable liner hanger may further comprise a first slip ring, wherein the first slip ring is disposed around the tubular body of the expansion element between the first spike and the second spike, wherein the first slip ring is configured to expand radially as the expansion element expands.

Abstract: It is discussed a method for drilling a well through a formation from a drilling installation, for the recovery of fluids, where a drill pipe (30) made up of a number of drill pipe sections is lead down into the formation and is supplied with liquid fluid from a fluid delivery system before one or more new drill pipe sections connected to the installations drill floor successively is screwed onto the upper end of the drill pipe (30), where a filling pipe (110) formed with a downwardly extending pipe spigot (17) that is lead down into the opening of the drill pipe section during assembly to start the fluid filling.

Abstract: A rotary guiding device includes a rotating shaft to rotationally drive a tool head. The rotating shaft includes upper and lower shaft portions, and a steerable portion, the upper shaft portion and the lower shaft portion are steerably connected by the steerable portion. A non-rotating body is mounted on the upper shaft portion, the non-rotating body is substantially non-rotating with respect to the rotating shaft in circumferential direction when the rotating shaft rotationally drives the tool head. The lower shaft portion includes a rib portion coinciding at least partially in axial direction with the non-rotating body. The non-rotating body includes at least three hydraulic driving mechanisms uniformly distributed along its circumferential direction, the three hydraulic driving mechanisms controllably generate radial drive forces respectively, the radial driving forces act on the rib portion overlapping the non-rotating body so the lower shaft portion can be deflectable relative to the steerable portion.

Abstract: A technique facilitates use of a submersible pumping system deployed downhole in a borehole. A docking assembly comprises a docking station which has at least one electrical wet connector and is coupled to a receiving tubular. An electrical power cable is coupled to the docking station to enable electrical power to be provided to the at least one electrical wet connector. The docking assembly is deployed downhole to a desired location in the borehole to enable coupling with the submersible pumping system. The submersible pumping system is simply moved downhole into the receiving tubular and into electrical engagement with the electrical wet connectors.

Abstract: A method of connecting a first threaded tubular to a second threaded tubular includes engaging the threads of the tubulars and rotating the first tubular relative to the second tubular to makeup a threaded connection. The method further includes, during makeup of the threaded connection: measuring time, measuring torque applied to the connection, and measuring turns of the first tubular. The method further includes using a programmable logic controller for: evaluating at least one of the measured turns, measured torque, and measured time for at least one of a discontinuity, a torque spike, and a torque drop and accepting or rejecting the connection based on the evaluation.

Abstract: A new method of gathering data real time during production or simulation tests using a gravity deployed tool, referred to as a fiber-line intervention tool (“FLI” or “FLIT”) to monitor bottom-hole pressure and temperature for well testing including the testing of adjacent wells is provided. In an embodiment, the tool is configured to include a housing, spooled fiber-line, sensors such as pressure and temperature sensors, and connections between the fiber-line and sensors such that measurement information from the sensors can be sent to the surface in real time over the fiber-line. As the housing is deployed into a well, the fiber-line can unwind, thereby providing a communication pathway from below the surface to above the surface. In an embodiment the housing can be deployed through a wellhead and down the wellbore. In an embodiment, the housing can be made of a soluble material.

Abstract: A method for recovering a conduit from a wellbore includes positioning an expander tool having at least one biasing element within the conduit an expander tool and exerting a force against the at least one biasing element to radially expand the conduit to an amount sufficient to fracture solids outside of and in contact with the conduit.

Abstract: A trailer-mounted drilling rig incorporates a dual top drive apparatus and a plurality of lifting assemblies useable for decreasing connection time of pipe segments useable during well drilling or other well operations, and methods of connecting pipe segments useable during well drilling or other operations. The plurality of lifting assemblies operatively connected to the dual top drive apparatus and a first lifting assembly is capable of moving a first top drive vertically inline with a wellbore while a second lifting assembly is capable of independently moving a second top drive vertically out of alignment with the wellbore.

Abstract: A first platform is mounted to a central riser that is configured to flow a fluid into or out of a wellbore. The central riser is fluidically and structurally attached to a wellhead. The first platform is positioned relative to the central riser to allow access to substantially all external portions of the central riser from the first platform. A second platform is positioned above and supported by the first platform. The first platform is positioned between the second platform and the wellhead. The second platform is movable relative to the first platform.

Abstract: A sliding member has a sliding surface sliding under a wet condition in which a lubricant oil exists. The sliding surface is coated with a laminate film comprising an upper layer and a lower layer. The lower layer comprises hydrogen-free amorphous carbon (hydrogen-free DLC) and carbon particles dispersed on or in the hydrogen-free DLC. The hydrogen-free DLC has a hydrogen content of 5 atom % or less when the lower layer as a whole is 100 atom %. The upper layer comprises boron-containing amorphous carbon (B-DLC) and has protrusions on a surface side of the upper layer along the carbon particles of the lower layer. The B-DLC has a boron content of 1-40 atom % when the upper layer as a whole is 100 atom %. The protrusions have a particle diameter of 0.5-5 ?m and exist with a density of 20 protrusions/100 ?m2 or more.

Abstract: The tool assembly vibrates a casing string or drill string in a wellbore. The tool assembly includes a housing, an insert mounted in the housing as a fluidic agitator, a coating on the insert, and a cover fitted over the insert. The coating on the insert provides erosion resistance and a smooth surface compatible with high velocity fluid flow required to achieve the strength and frequency of desired high strength and low frequency pressure pulses.

Abstract: A tubular handling system and method, of which the system includes a power tong configured to engage and rotate an add-on tubular by applying a torque thereto, the power tong defining a central opening configured to receive the add-on tubular therethrough, a spider disposed at a rig floor, the spider being configured to support a tubular string, a lifting assembly coupled with the power tong and configured to move the power tong vertically with respect to the tubular string and the spider, and a control line guide coupled to the power tong. The control line guide is movable between an extended position in which the control line guide is configured to guide a control line into close proximity to the add-on tubular, and a retracted position in which the control line guide is configured to maintain a lateral control line clearance gap between the control line and the add-on tubular.

Abstract: The present invention relates to an attachment for drilling and/or foundation work, in particular a casing oscillator or casing rotator, comprising a receiving apparatus for clamping at least one pipe and a drive for generating a rotational movement of the clamped pipe, wherein the attachment comprises at least one integral control unit for an independent carrying out of control functions of the attachment.

Abstract: A combined multicoupler for connecting a tool to a top drive is disclosed. The combined multicoupler includes a load frame comprising a frame body having a load shoulder, and a side door coupled to the frame body. The side door opens from the frame body to allow a tool sliding horizontally into the load shoulder, and the side door closes to lock the tool in the load frame. The combined multicoupler further comprises a drive stem movably coupled to the load frame, wherein the drive stem moves vertically to connect and disconnect with the tool in the load frame.

Abstract: A self-calibrating system, apparatus, and method for accurately measuring a volumetric capacity of a tank. The system, apparatus and method comprise: a mechanism that adjusts a level of a platform; a light-emitting device with beam-like optics (laser, diode, etc.) mounted to the platform; mechanism for adjusting alignment of the light-emitting device with respect to the platform; a mechanism for rotating the platform by variable angles, including by 180-degrees; one or more level sensors (such as, for example, spirit levels, tilt sensors, or other devices) that provide feedback on the alignment of the platform normal to the gravity vector.

Abstract: A connector assembly attaches downhole tools to one another to form a tool string. The connector assembly includes male and female subs, each with latch ends that selectively latch to one another. Ends of the subs distal from their latch ends are configured for attachment to the downhole tools. A plug assembly is in one of the subs and a socket assembly is disposed in the other sub; the plug and socket assemblies mate with one another when the subs attach. Mating the plug and socket assemblies forms a signal communication path through the connector assembly so that adjacent tools are in signal communication. The plug and socket assemblies and male and female subs are annular and circumscribe a bore that extends axially through the connector assembly. Downhole tools that attach to opposing ends of the connector assembly are in communication through the bore in the connector assembly.

Abstract: A well pumping assembly has a stator mounted in a housing, the stator having an axially extending stator cavity. The stator has windings that when powered create an electromagnetic field into the stator cavity. A pump has a landed position within the stator cavity. The pump having a non-rotating pump portion and a rotating pump portion. Magnets mount on the rotating pump portion and impart rotation to the rotating pump portion in response to the electromagnetic field. A neck on a downstream end of the pump has a running and retrieval feature for engagement by a running and retrieving tool to retrieve the pump from and install the pump in the landed position.

Abstract: A centralizer device for center positioning of a bore hole component (90, 91) in a bore hole and a method for deploying such a centralizer are described. The centralizer device (100) is prepared to have two possible different states, one state being a locked state for improved deployment and another state being a released state for centring. The transition from the locked state to the released state is performed by introducing a pill of bore fluid having a pH-value outside range of pH-values of bore fluid in a well. The pill of bore fluid dissolves pH-soluble material in the centralizer device.

Abstract: A duplex snubbing jack and method of snubbing pipe into a well bore which includes first and second gripping units that alternately and synchronously grip and release a length of pipe to be attached to a pipe string. The first and second gripping units are synchronously movable upward and downward toward and away from each other to push or pull the pipe through a BOP stack and into or out of a wellbore. Linear actuators are used to synchronously move the first and second gripping units. Guide rails are provided to laterally support the pipe as the pipe is pushed or pulled through the BOP stack into or out of the wellbore. The first and second gripping units are preferably slip-type spiders.

Abstract: A method sequence for handling tubulars into or out of a wellbore, the method comprising: moving a tubular string into or out of a wellbore via a top drive; moving tubular stands to and from a setback position and a stand handoff position via a transfer bridge racker and a setback guide arm; moving tubular stands to and from the stand handoff position and a well center position via a tubular delivery arm and a lower stabilizing arm; building stands and breaking down stands offline via a mousehole and operating a roughneck on joints between the tubular stands and the tubular string.

Abstract: In combination a drilling installation for drilling a well and a control and signal lines deployment module, wherein the drilling installation includes a rig floor slip device which is adapted to be cleared from a well centre opening to create a clear space around the well centre opening. The combination further includes a temporary workspace floor, which is adapted to be mounted in the clear space at a level below a rig floor surface and to provide a workspace floor for an operator standing in the clear space on said work space floor, allowing the operator to secure at a securing level the one or more control/and or signal lines externally to a second tubulars string suspended from a module slip device.

Abstract: A pipe handler for handling tubular members of a well system includes a mounting member for mounting the pipe handler to a structure of the well system, a first arm having a first end coupled to a structure of the well system, and a second end, wherein the first arm is configured to pivot relative to the mounting member about a first axis, a second arm having a first end and a second end, a connector coupled to the second end of the first arm and the first end of the second arm, and wherein the connector is configured to rotate the second arm about a second axis and a guide member coupled to the second end of the second arm for guiding a tubular member, wherein the second arm is configured to pivot relative to the connector about a third axis.

Abstract: A technique facilitates joining of sections of tubing and related monitoring. An expandable tubular member may be coupled with an external tubing, e.g. a casing. The expandable tubular member is deployed into the external tubing to a desired position. Then, an expandable portion of the expandable tubular member may be plastically deformed in a radially outward direction and into engagement with the external tubing. A sensor system may be combined with the expandable tubular member to monitor a characteristic of the expandable tubular member.

Abstract: A floor wrench for a drilling rig floor is provided. The wrench can include a tong assembly having upper and lower tongs made up of articulated tong blocks that can move and lock together to enclose and make or break a joint between sections of drilling pipe. Each tong block can include a pair of die ram assemblies wherein each tong can have dies to grip the drilling pipe around its circumference. The tong assembly can be mounted in a frame configured for horizontal and vertical movement to and from the pipe joint. In some embodiments, the wrench can further include a pipe spinner having motorized spinners that can spin the upper pipe to form the joint prior to torqueing the joint together, or for uncoupling the upper pipe after the joint is broken.

Abstract: The present invention discloses a method of plugging a well that relies on casing expansion to plug uncemented casing sections, rather than milling out the casing or perforate wash and cement (PWC).

Abstract: A system and method for continuous mud circulation during a drilling operation, of which the method includes delivering a first flow of drilling mud to and through a blowout preventer via a drill string and a wellbore. The method also includes delivering a second flow of drilling mud to and through the blowout preventer. The second flow is delivered to the blowout preventer through an alternative line and not via the drill string. The method also includes stopping the first flow of the drilling mud, and adding or removing a tubular to or from the drill string after the first flow of drilling mud is stopped and while continuously delivering the second flow of drilling mud. Adding or removing the tubular includes decoupling a rotating control device from the blowout preventer, detachably coupling the rotating control device with a drag device, and raising or lowering the rotating control device with the drag device coupled therewith.

Abstract: A method is for hydrocarbon resource recovery. The method may include positioning an RF antenna assembly within a wellbore in a subterranean formation, the RF antenna assembly having first and second tubular conductors and a dielectric isolator defining a dipole antenna, and a dielectric coating surrounding the dielectric isolator and extending along a predetermined portion of the first and second tubular conductors. The method may include operating an RF source coupled to the RF antenna assembly during a start-up phase to desiccate water adjacent the RF antenna assembly, and operating the RF source coupled to the RF antenna assembly during a sustainment phase to recover hydrocarbons from the subterranean formation.

Abstract: A system for radially expanding a tubular element (2) in an underground borehole (3) comprises an expansion string (16) extending into the tubular element (2) and including an expander (27) and a jack device (24) for pulling the expander (27) through the tubular element (2) so as to radially expand the tubular element (2). The jack device (24) is provided with an anchor (28) having at least one slip element (50) adapted to be radially moved against the inner surface of the tubular element (2). A cage (14) is positioned above the tubular element (2), which cage (14) is surrounded by a cylindrical wall and adapted to receive the anchor (28) and to be radially expanded by the anchor (28) against said cylindrical wall.

Abstract: A downhole tool includes a tool body and a first anchoring device integrated with the tool body. The first anchoring device includes at least two linear actuators within and non-perpendicular to the tool body, each of the at least two linear actuators configured to move a corresponding contact pad between a retracted position and an anchor position. The first anchoring device also includes at least one guide component coupled to each contact pad to restrict movement of a corresponding contact pad to a predetermined path.

Abstract: A device and drilling rig are disclosed for suspending loads from a bail or an elevator of such drilling rig, and method therefor. The device includes an upper bail clamp for clamping around the bail, a lower bail clamp for clamping around the bail, and a connecting part which is connected to the upper bail clamp by means of upper connecting means and connected to the lower bail clamp by means of lower connecting means. The connecting part is further provided with a coupling means for connecting the connecting part to the load to be suspended from the bail. At least one of the upper connecting means allow translational movement of the connecting part with respect to one of the upper bail clamps, while another of the connecting means are arranged to prevent translational movement of the connecting part with respect to the other of the lower bail clamps.

Abstract: In an assembly for lowering and expanding a tubular element in a borehole on an expansion string, at least part of the weight of the tubular element is transmitted to the expansion string via an internal upset and a support protruding from an outer surface of the expansion string below the internal upset.

Abstract: Systems and methods for positioning tubular members within a subterranean well include inner and outer tubular members extending into the well. An adjustment ring assembly is located between the inner tubular member and the outer tubular member and has an outer ring and an inner ring. The outer ring circumscribes, and is rotatable relative to, the inner ring to adjust the radial offset between a central axis of the wellhead assembly and a central axis of the inner tubular member.

Abstract: The method and apparatus for producing shock waves in a well including a device connected to the bottom of the tubing string in a borehole of the well filled by liquid and containing the upper and lower plungers movably arranged within corresponding cylinders for compressing a liquid inside the compression chamber and discharging the liquid into the borehole on upstroke thereby generating a shock wave. In addition, a length of upstroke Lstr is determined by the following expression: L str ? H 1 + ( D 1 2 - D 2 2 ) ? A sw ? L 2 Ed r 2 , where H1 is a length of a lower cylinder, L2 is a distance between lower and upper plungers, D1 is a diameter of the lower plunger, D2 is a diameter of the upper plunger, Asw is a required amplitude of a generated shock wave, E is an elasticity modulus of a sucker rod's material, dr is a diameter of the sucker rods.

Abstract: A perforating gun string may include a first perforating gun; a second perforating gun axially offset from the first perforating gun; a connector configured to interpose and couple the first and second perforating guns; and a detonation cord that passes axially through a central bore of the connector; and is connected to the first and second perforating guns. In some instances, the connector may have a body with an inner surface that defines the central bore, wherein the body has a ratio of an average diameter of the outer surface to an average diameter of the inner surface of about 1.2 to about 4.

Abstract: A method and apparatus for a drive unit of a top drive system including a first, second, and third drive gears that are operationally coupled; a motor engagable with the first drive gear; a drive stem having a load coupling and engagable with the second drive gear; and a torque shaft having a torque coupling and engagable with the third drive gear. The drive stem cannot engage with the second drive gear when the torque shaft is engaged with the third drive gear. A method of coupling a drive unit to a tool adapter includes engaging a first drive gear with a motor of the drive unit while engaging a second drive gear with a drive stem of the drive unit; coupling a load between the drive stem and a tool stem of the tool adapter; and coupling a torque between a torque shaft of the drive unit and the tool stem.

Abstract: A structure for directly leading down the optical unit (OU) from the OPPC (optical phase conductor) cable, by the OU leading-down connector (2) invented recently, is used for separating the plastic-pipe OU from the OPPC cable installed on the tower, avoiding the splicing of fibers on the tower of the old technique. Therefore it is possible to assemble the OPPC cable (1), the OU leading-down connector (2), the preformed armor rod assembly (3), the first link fitting (4), the residual cable rack (5), the second link fitting (6), the insulator string (7) on the ground all together. Then the whole assemble can be erected on to the tower. Just as the conventional overhead power line construction. So it is simple and saving in work.

Abstract: An apparatus comprises a first number of splines located near a first end of a first joint section and a second number of splines located near a second end of a second joint section. The first number of splines extends in an axial direction of the first joint section and spans a circumferential surface of the first joint section. Each of the first number of splines has a base, a tip, and a pair of flanks that extends from the base to the tip and forms an acute angle. Each of the first number of splines are configured to be received between adjacent pairs of splines in the second number of splines as the first end of the first joint section and the second end of the second joint section are joined.

Abstract: A wellscreen assembly has first and second screen joints connected together and has at least first and second adjoining tubes with opposed ends separated by a gap from one another. At least one jumper tube has first and second tubulars and fits in the gap between the adjoining tubes. The first tubular has a first end connectable to one of the opposed ends, while the second tubular has a second end connectable to another of the opposed ends. The second tubular is telescopically connected to the first tubular, and a biasing element biases the first and second tubulars away from one another. The first and second tubulars are operable between (i) a retracted condition retracting the first and second ends from the opposed ends and (ii) an extended condition extending the first and second ends to the opposed ends of the adjoining tubes.

Abstract: An apparatus comprises a first number of splines located near a first end of a first joint section and a second number of splines located near a second end of a second joint section. The first number of splines extends in an axial direction of the first joint section and spans a circumferential surface of the first joint section. Each of the first number of splines has a base, a tip, and a pair of flanks that extends from the base to the tip and forms an acute angle. Each of the first number of splines are configured to be received between adjacent pairs of splines in the second number of splines as the first end of the first joint section and the second end of the second joint section are joined.

Abstract: A flow sub for use with a drill string includes a tubular housing having a longitudinal bore therethrough and a flow port through a wall thereof and a ball. The ball is disposed in the housing above the flow port, has a bore therethrough, and is rotatable relative to the housing between an open position where the ball bore is aligned with the housing bore and a closed position where a wall of the ball blocks the housing bore. The flow sub further includes a seat disposed in the housing above the ball for sealing against the ball wall in the closed position and a sleeve disposed in the housing and movable between an open position where the flow port is exposed to the housing bore and a closed position where a wall of the sleeve is disposed between the flow port and the housing bore.

Abstract: The disclosure provides a system and process for drilling a subterranean wellbore. An embodiment includes a bottom-hole assembly for a downhole mud motor that incorporates an information sub, such as a measurement-while-drilling or logging-while-drilling tool, at a location below, or down-hole from, the mud motor. The assembly also includes a micronized bit-to-bend length, or a length between a forward end of the assembly's bearing mandrel and a fixed bend in the assembly's housing, of less than or equal to forty inches. The combination of the forward-located information sub and micronized bit-to-bend length allow the driller to rely on real-time data relating to conditions adjacent to the drill bit/bottom of the wellbore and take that real-time drilling data into account in steering the bit along a planned wellbore trajectory. Other embodiments are also disclosed.