Abstract: A drilling composition is provided. The composition includes: I) an organic phase comprising components: i. from about 20 wt. % to about 99.999 wt. %, based on the total weight of components i. and ii., of at least one linear or branched, cyclic or non-cyclic, saturated hydrocarbon; ii. from about 0.001 wt. % to about 25 wt. %, based on the total weight of components i. and ii., of at least one ester; II) from 0 to about 50 wt. %, based on the total weight of the composition, of water or aqueous phase; Ill) from 0 to about 60 wt. %, based on the total weight of the composition, of at least one additive, wherein the sum of the weight components I) to III) is 100 wt. %.

Abstract: The mining vehicle has a carriage, driving equipment for moving the carriage, at least one mining work device, an electric motor for supplying power to the mining work device, a connection for supplying electric power to the electric motor from an electrical network of the mine, and an energy source. The electric motor has at least a primary stator winding and a secondary stator winding galvanically isolated from each other. When the mining vehicle is connected to the electrical network of the mine via the primary stator winding, the electric motor is arranged, at least for a period of time, to supply power to the at least one mining work device and, at least for a period of the time, to supply power via the secondary stator winding for charging the energy source. A method for energy supply of a mining vehicle is also provided.

Abstract: Disclosed are methods for solution mining of evaporite minerals, such as trona, comprising drilling an access well and at least two lateral boreholes; injecting a fluid; circulating the fluid through the lateral boreholes with a controlled fluid flow; and collecting a pregnant solution. Also disclosed are methods of solution mining that include injecting an aqueous solution into an underground trona cavity at a temperature sufficient to maintain at least a portion of the solution in the cavity in the Wegscheiderite solid phase region; removing aqueous solution from the cavity; and recovering alkaline values from the removed aqueous solution. Also disclosed are methods of solution mining that include injecting an aqueous solution into an underground trona cavity; removing aqueous solution from the cavity, wherein the temperature of the removed aqueous solution is at about the TWA point temperature; and recovering alkaline values from the removed aqueous solution.

Abstract: The invention provides an electrical conductor subassembly and a method of constructing an isolated electrical connection comprising a set of the connected electrical conductor subassemblies. Each subassembly is connectable with other of the subassemblies into a conductor string while being fed into an opening in a hole or pipe, thereby enabling an electrical connection along the conductor string that is electrically substantially isolated from external fluids in the hole or pipe. Each conductor subassembly comprises: a conductor segment with a conductor core surrounded by an insulating layer; two connectors attached to opposite ends of the conductor segment, having two respective conductor engagement elements attached to corresponding ends of the conductor core. The connectors of adjacent conductor subassemblies are connectable securely against forces in the hole or pipe and so as to electrically join their corresponding conductor engagement elements and seal them from contact with the external fluids.

Abstract: The subject matter of this specification can be embodied in, among other things, a tool string positionable in a wellbore that includes a spur gear driven by a source of input rotation, a planetary gearbox having an attachment structure to connect to the spur gear. The gearbox includes a central sun gear, a collection of planet gears disposed in a planet gear carrier disposed around the central sun gear, and a ring gear disposed around the planet gears and planet gear carrier. The attachment structure drives a hydraulic pump or electrical generator at a rotational speed different than a rotational speed of the source of input rotation.

Abstract: A method of hydraulically activating a mechanically operated wellbore tool in a bottom hole assembly includes: holding moveable elements of the wellbore tool in an unactivated position using a shear pin; inserting one or more drop balls into a drilling fluid; and flowing the drilling fluid with the drop balls to a flow orifice located in or below the wellbore tool. The flow orifice is at least partially plugged with the drop balls to restrict fluid flow and correspondingly increases the hydraulic pressure of the drilling fluid. The hydraulic pressure is increased to a point beyond the rating of the shear pin, thereby causing the shear pin to shear and allowing the moveable elements of the tool to move to an activated position.

Abstract: The present invention relates in general to subsurface drilling tools, and more specifically, to a drill bit comprising a ball shaped cutting tool. The drill bit is configured so that a plurality of cones, forming the ball shaped cutting tool, rotate in opposite directions around an axle while the drill bit is drilling or cutting through the ground, rock, or other material. The drilling or cutting is accomplished by a plurality of blade inserts that fit inside and protrude therefrom a plurality of holes covering the exterior of the ball shaped cutting tool. The purpose of the present invention is to provide a new and improved subsurface drilling tool that will efficiently drill hard rock formations.

Abstract: The expandable tools disclosed herein may be used as an underreamer to enlarge a borehole, or may be used to stabilize a drilling system in a previously underreamed borehole or in a borehole that is being underreamed while drilling progresses. At least one moveable arm, which translates between a collapsed and expanded position in response to a differential pressure between the axial flowbore and the wellbore, includes a borehole-engaging surface with cutting elements and at least one nozzle to direct a fluid across the borehole-engaging surface. Flow directing elements on the external surface of the tool may be used to decrease the flow area in an annulus between the tool and the wellbore and directs fluid flow in the annulus toward the borehole-engaging surface.

Abstract: A method of drilling a wellbore includes drilling the wellbore through a formation by injecting drilling fluid through a drill string and rotating a drill bit. The drill string includes a shifting tool, a receiver in communication with the shifting tool, and the drill bit. The method further includes retrieving the drill string from the wellbore through a casing string until the shifting tool reaches an actuator. The casing string includes an isolation valve in an open position and the actuator. The method further includes sending a wireless instruction signal to the receiver. The shifting tool engages the actuator in response to the receiver receiving the instruction signal. The method further includes operating the actuator using the engaged shifting tool, thereby closing the isolation valve and isolating the formation from an upper portion of the wellbore.

Abstract: A coaxial ground heat exchanger and installation method are disclosed where the heat exchanger has a central core tube that can be provided with a thermally insulating casing and an outer tube that delimits an annular gap which extends radially outwards from the core tube. The core tube and the annular gap can be configured such that a flowable heat transfer medium can flow through. The outer tube is formed by a tubular expandable cover that directly adjoins a wall of a ground heat exchanger borehole when the heat exchanger is installed.

Abstract: A drill head clean out device having a clean out tool, a first bar having a first end and a second end, wherein the clean out tool is adapted to be positioned on the first end of the first bar, a coupling member having a first aperture adapted to receive the first bar when the first bar is in a vertical orientation, a second bar having a first end and a second end, wherein the coupling member has a second aperture adapted to receive a first end of the second bar when the second bar is in a horizontal orientation, and wherein the second end of the second bar is adapted to be positioned within an aperture in a base of a drill rig.

Abstract: A downhole tool for increasing a diameter of a wellbore disposed within a subterranean formation. The downhole tool includes an underreamer having a plurality of cutter blocks moveably coupled thereto that move radially-outward from a refracted state to an expanded state. The cutter blocks cut the subterranean formation to increase the diameter of the wellbore from a first diameter to a second diameter when in the expanded state. A formation weakening tool may be coupled to the underreamer. The formation weakening tool weakens a portion of the subterranean formation positioned radially-outward therefrom.

Abstract: An electric horizontal directional drilling machine. An electric horizontal directional drilling machine is powered by an electric power assembly. The power assembly is made up of a fuel cell and inverter, or multiple fuel cells with synchronized inverters. The electric motor operates hydraulic pumps or works independently to rotate, advance and retract a drill string and downhole tool through the earth and operate various machine functions. Mechanical functions of the drilling machine may also be satisfied through the use of electric rotary actuators (e.g., motors) and linear actuators (e.g., linear motors and solenoids).

Abstract: A downhole reaming system includes a tubular body having a drill bit disposed on a distal end thereof, and a central bore therethrough, wherein the tubular body is attached to a drillstring, an expandable reamer having cutter blocks coupled thereto and configured to selectively expand radially therefrom, a near-bit reamer disposed proximate the drill bit, the near-bit reamer having cutter blocks coupled thereto and configured to expand therefrom, and a measurement sub configured to measure at least one characteristic of an interior wall of an enlarged wellbore.

Abstract: An apparatus for use downhole is disclosed that, in one configuration includes a downhole tool configured to operate in an active position and an inactive position and an actuation device, which may include a control unit. The apparatus includes a telemetry unit that sends a first pattern recognition signal to the control unit to move the tool into the active position and a second pattern recognition signal to move the tool into the inactive position. The apparatus may be used for drilling a subterranean formation and include a tubular body and one or more extendable features, each positionally coupled to a track of the tubular body, and a drilling fluid flow path extending through a bore of the tubular body for conducting drilling fluid therethrough. A push sleeve is disposed within the tubular body and coupled to the one or more features.

Abstract: A turbodrill having a housing having a bore extending at least partially therethrough, a rotatable shaft disposed in the housing bore and rotatable relative to the housing, the housing, the housing bore and the rotatable shaft having a common longitudinal axis; and a plurality of turbine blades disposed at least partially within the housing bore, at least one turbine blade of the plurality of turbine blades including a first blade profile disposed at a first point along a blade span and a second blade profile disposed at a second point along the blade span, the second blade profile differing from the first blade profile.

Abstract: An operations fluid is provided for treatment operations on wellbores associated with hydrocarbon production, the operations fluid comprising: water, an inorganic primary acid; and an alkyl acid surfactant. The alkyl acid surfactant has the general formula {R—X}, wherein R comprises at least one of linear and branched alkyl and alkyl aryl hydrocarbon chains and X comprises an acid, and X may comprise an acid selected from the group comprising sulfonic acids, carboxylic acids, phosphoric acids, and mixtures thereof. The alkyl acid may include an acid selected from the group consisting of alkyl or alkyl aryl acids. The operations fluid may be useful in treatment operations related to formation stimulation or mitigation of non-aqueous filter cakes (NAF) and/or formation invasion by NAF drilling fluids.

Abstract: A high pressure seal adapter for a conductor housing of a wellhead, and a method of completing a well having a conductor housing attached thereto, are disclosed. The high pressure seal adapter has a unitary body including a first circular bore extending through the unitary body. The first circular bore has a circular perimeter extending beyond a centerline of the unitary body. The unitary body further includes a second circular bore adjacent the first circular bore and extending through the unitary body. The seal adapter is configured to be installed in the conductor housing. The method includes providing such a high pressure seal adapter and installing the high pressure seal adapter in the conductor housing.

Abstract: A drill bit is disclosed. The drill bit includes a center member configured to rotate at a first speed and an outer member disposed outside the center member, wherein the outer member is configured to rotate at a second speed. The drill bit also includes a first cutter disposed on the center member and a second cutter disposed on the outer member, wherein the first speed and second speeds are configured to control a resultant side force of the drill bit.

Abstract: An efficient and eco-friendly oil drilling system includes at least one storage tank, an initial surface drilling system and a subsequent drilling system, a plurality of rig mud pumps, and a drilling rig. The plurality of rig mud pumps is in fluid communication with the drilling rig as the drilling rig is in fluid communication with the at least one storage tank. The initial surface drilling system that drills a surface hole for an oil well and the subsequent drilling system that drills a borehole for the oil well are selectively in fluid communication with the plurality of rig mud pumps, where the initial surface drilling system is utilized prior to the subsequent drilling system to optimize the efficiency of the drilling process.

Abstract: A downhole tool including a body configured to be positioned on an outer surface of a tubular. A flexible member may extend circumferentially around the body more than once. The body may be positioned radially-between the outer surface of the tubular and the flexible member, and a tension force on the flexible member may cause the flexible member to apply a radially-inward gripping force on the body and the tubular.

Abstract: A drill bit assembly that includes a shank including a shank axis, first and second ends, a drill bit seat at the second end and a central flow bore extending axially from the first end. Additionally, the assembly includes a sleeve disposed about and translatable axially relative to the shank and a drill bit rotatably coupled to the sleeve. The drill bit includes a first bit face having a first cutting structure configured to engage an earthen formation, and a second bit face having a second cutting structure configured to engage the earthen formation. The drill bit is configured to rotate about the about the shank axis in a cutting direction, and to rotate about an axis of rotation being orthogonal to the shank axis to selectively expose the first or second cutting surface to the earthen formation. The seat is configured to receive the first or second bit face.

Abstract: A substructure of a drilling rig is positioned above a first wellbore at a first wellbore location, a drilling rig mast is pivotably attached to the substructure and raised from a first mast position wherein an upper end of the drilling rig mast is oriented in a first direction toward a first side of the substructure to a first raised drilling position, after which a first drilling operation is performed on the first wellbore. The substructure is moved to a second wellbore location and positioned above a second wellbore, the drilling rig mast is pivotably attached to the substructure and raised from a second mast position wherein an upper end of the drilling rig mast is oriented in a second direction toward a second side of the substructure to a second raised drilling position, after which a second drilling operation is performed on the second wellbore.

Abstract: A cleat anchoring system is disclosed for anchoring a mobile equipment rig using the dead weight of the mobile equipment rig to assist with anchoring. In one embodiment, an anchoring method generally comprises providing front and rear cleat pad assemblies. The rear cleat pad assembly is laid on a ground surface at a first desired position so that cleats on the rear cleat assembly engage the ground surface. The mobile equipment rig is moved to stand on the rear cleat pad assembly. The front cleat pad assembly is then laid on the ground surface at a second desired position so that cleats on the front cleat assembly engage the ground surface. A thrust plate associated with the rig is positioned to stand on the front cleat assembly. The front and rear cleat pad assembles are then rigidly connected.

Abstract: A pressure pulse generating method and apparatus for use with a drill string includes a top and bottom subs for attaching the apparatus within the drill string; a power section comprising a rotor/stator; a drive assembly; and a nozzle sub which includes a nozzle assembly comprising a nozzle holder and a replaceable nozzle; and a nozzle housing having pulse openings. The nozzle holder has fluid ports which periodically align with the pulse openings as the nozzle holder rotates within the nozzle housing to achieve a desired pulse amplitude, frequency and waveform.

Abstract: Systems and methods for accessing and/or harvesting hydrocarbons from a wellbore. A method may include modeling a well to determine a length of a stimulation zone in the production interval, wherein the model is based, at least in part, on a reaction time for a stimulation process. Packers are placed in the well to fluidically isolate the stimulation zone from other zones in the well. The targeted zone is stimulated, such as by acid treatment. Hydrocarbons may be recovered from the stimulation zone.

Abstract: A method of drilling and fracturing a well includes installing a drilling/frac adapter on a lower wellhead housing. The drilling/frac adapter has a higher internal pressure rating than the lower wellhead housing. The operator drills through the drilling/frac adapter to a desired depth, then runs and cements a casing string in the well. A lower packoff is installed in an annulus between the casing hanger and the lower wellhead housing and an upper packoff is set in an annulus between the drilling/frac adapter and the casing hanger. Frac fluid is pumped through the frac tree into the casing string at a higher pressure than the pressure rating of the lower housing but less than the pressure rating of the drilling/frac adapter. Then, the upper packoff and the drilling/frac adapter are removed from the lower housing and installing an upper wellhead housing on the lower wellhead housing.

Abstract: Apparatus and methods for controlling drill string vibrations and applying a force to a drill bit include a body having a first piston at an uphole end in association with a drill string and a second piston at a downhole end in association with a drill bit. A first biasing member urges the first piston outward to provide a first force in an uphole direction to the drill string. A second biasing member urges the second piston outward to provide a second force in a downhole direction to the drill bit. When vibration from the drill string compresses the first biasing member, the first force resists the vibration and maintains the apparatus and drill bit in a consistent orientation. When an uphole force from the drill string or the drill bit compresses the second biasing member, the second force prevents movement of the drill bit in an uphole direction.

Abstract: A drilling system includes a drillstring and a power section further including a stator having a stator axis and a rotor within the stator. The rotor rotates eccentrically within the stator in response to fluid flowing therebetween. Additionally, the system includes a coupling section including first, second, and third rotation members having a first, second, and third axes, respectively. The third rotation member is coupled to the first and second rotation members. The third rotation member is configured to move radially relative to the first and second rotation members as the first, second, and third rotation members rotate about the first, second, and third axes, respectively. Further, the system includes an input shaft coupled to the rotor and first rotation member. The input shaft and first rotation member rotate with the rotor eccentrically to the stator axis and the second rotation member rotates concentrically about the stator axis.

Abstract: A mud lift pump for a dual drill string includes an energy input and an energy output in fluid communication with a fluid return flow passage in the dual drill string.

Abstract: A drilling assembly is tripped in a cased hole to make more open hole. The assembly features retracted scrapers and a closed circulation sub so that the drilling can commence with string pressure delivered to bit nozzles due to the circulation sub being in a closed position. When drilling is done and the bit is to be removed, an object lands on a seat on a sleeve that acts as a piston to break scraper retainers for casing scraping deployment and to open the circulation port. A bypass opens around the seated ball when the sleeve shifts to allow flow around the seated ball for circulation while scraping. Drilling and casing scraping are accomplished in a single trip.

Abstract: A method for drilling a borehole in an earthen formation comprises (a) providing a drilling system including a drillstring having a longitudinal axis, a bottom-hole assembly coupled to a lower end of the drillstring, and a drill bit coupled to a lower end of the bottom-hole assembly. In addition, the method comprises (b) rotating the drill bit at a rotational speed. Further, the method comprises (c) applying weight-on-bit to the drill bit and advancing the drill bit through the formation to form the borehole. Still further, the method comprises (d) pumping a drilling fluid down the drillstring to the drill bit. The drilling fluid has a flow rate down the drillstring. Moreover, the method comprises (e) oscillating the rotational speed of the drill bit during (c). The method also comprises (f) generating non-steady state conditions in the borehole during (e).

Abstract: Systems and methods contain fluids discharged from a subsea well or at the surface by capping the well blowout with a pre-positioned capping device. The capping device includes at least one blind shear ram and is separate from a blowout preventer. The blowout preventer may operate to control well events up to a certain pressure, above which the capping device is employed since the capping device has a higher pressure rating than the blowout preventer.

Abstract: A method for forming a subsurface wellbore is disclosed. The method includes operating a drilling string in a first direction of rotation. A first motor located near the end of the drilling string is operated in a direction of rotation opposite that of the drilling string. A drill bit is rotated using a second motor that is coupled to the first motor.

Abstract: Methods of procuring a core sample may involve engaging an earth formation with a cutting structure of a coring bit. A core sample may be received within a receptacle connected to the coring bit, the receptacle being lined with a sponge material. A space of about 1 mm or less may be maintained between the core sample and the sponge material. Coring tools may include a coring bit comprising an inner gage and an outer gage and a sponge material positioned to at least partially surround a core sample cut by the coring bit. A radial distance between an inner surface of the sponge material and the inner gage of the coring bit may be about 1 mm or less. A distance between a center of curvature of the inner gage and a center of curvature of the outer gage may be about 0.3 mm or less.

Abstract: Modular transfigurable drilling rig system composed of multiple components, which system is transfigurable between a transport mode in which the components of the system are transportable and an operational mode in which the components are assembled to a drilling rig which is adapted to drill into a well centre in the ground.

Abstract: An under-reamer includes a body and extendable cutters mounted on the body. The under-reamer is configured to be cycled between a first configuration in which the cutters are retracted and a second configuration in which the cutters are movable between retracted and extended positions. A control mechanism is provided and is configurable to prevent the under-reamer cycling between the first and second configurations and thus maintains the under-reamer in a selected one of the first and second configurations.

Abstract: Downhole cutting systems, devices and methods for utilizing 10 kW or more laser energy transmitted deep into the earth with the suppression of associated nonlinear phenomena. Systems and devices for the laser cutting operations within a borehole in the earth. These systems and devices can deliver high power laser energy down a deep borehole, while maintaining the high power to perform cutting operations in such boreholes deep within the earth.

Abstract: Cutting elements for downhole cutting tools comprise a top surface having a cutting surface portion and a cutting profile disposed across the top surface. The cutting elements comprise first and second longitudinal side surfaces and first and second lateral side surfaces, each having a respective cross-section. The cutting profile can be disposed on the cutting surface either asymmetrically or symmetrically. Asymmetrical disposition permits two cutting elements to be arranged facing each other to cover a center point of a cutting tool. The cutting edge of asymmetrical or symmetrically disposed cutting profiles can have a shape that facilitates self-sharpening during cutting.

Abstract: A downhole tool assembly is configured for repeated and selective hydraulic actuation and deactuation. A piston assembly is configured to reciprocate axially in a downhole tool body. The piston assembly reciprocates between a first axial position and second and third axial positions that axially oppose the first position. The downhole tool is actuated when the piston assembly is in the third axial position and deactuated when the piston assembly is in either of the first or second axial positions. A spring member biases the piston assembly towards the first axial position while drilling fluid pressure in the tool body urges the piston assembly towards the second and third axial positions. Downhole tool actuation and deactuation may be controlled from the surface, for example, via cycling the drilling fluid flow rate.

Abstract: An apparatus for transmitting torque to a down hole motor in a down hole drilling assembly. The apparatus includes a center rod having a distal protuberance and a proximal protuberance, a transmission adapter having a first end connected to the down hole motor, and a transmission socket formed within a second end of the transmission adapter and configured to receive the proximal protuberance. A material bridge may be provided for the protuberances. The apparatus may also include a bearing adapter operatively connected to the center rod, with the bearing adapter having a bearing socket therein, and wherein the transmission adapter is configured to connect to an output of the down hole motor and the bearing adapter is configured to connect to an input of a bearing assembly in the down hole assembly for drilling the well. The adapters may contain external threads and the caps may contain cooperating internal threads. A method of drilling a well is also disclosed.

Abstract: A roller cone drill bit having detachable rotatable arms. The arms are connected at a mounting pad to the bit body. Each arm has its own grease delivery system to provide lubrication to the interface between the arms and rolling elements at an end of each arm. The forward-facing contact surface between the bit body and the arms is at an angle, relative to the central axis of the bit, that is ninety degrees or more.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to couple a stator to a borehole, and to move a rotor relative to the stator to generate electrical current to power a borehole tool.

Abstract: A modular tool for use in subterranean formations includes a first module, a second module and one or more connectors for connecting the first and second modules. In particular, the first module includes a first collar that at least partially defines an exterior of the tool and that includes a first engagement mechanism at a first end of the collar and a second engagement mechanism at a second end of the collar. The first module also includes a fluid passageway for passing drilling fluid therethrough. The second module has a similar configuration as includes similar architecture. The one or more connectors facilitate the connection of at least one flowline fluidly connected to an exterior of the tool, and an electrical pathway for transmitting power and/or data between the modules.

Abstract: A drilling device and method with a drill rod which can be driven in a rotating manner and has an internal line, a support rope, a rotary joint between the drill rod and the support rope and has a holding member which is in connection with the support rope and a rotary member which is in connection with the rotatable drill rod, a line and a rotary feed-through which is designed for the passage of fluid and/or data between the line and the internal line of the drill rod, wherein the rotary feed-through has a rotor connected to the drill rod and a non-rotating stator, to which the line is attached. Provision is made for the support rope to be designed in a torsion-proof manner and for a rigid connecting element to be arranged as a torque support between the stator of the rotary feed-through and the torsion-proof support rope.

Abstract: A downhole tool may be used to enlarge and widen a wellbore. The downhole tool may include a reamer with a mandrel that includes a rib extending radially outward from a cylindrical body of the mandrel. The rib may define one or more grooves. A cutter block or other expandable member may be positioned adjacent the rib and may include one or more extensions that mate with the grooves. The rib and cutter block may be positioned within a slot of a housing. The housing may also include one or more grooves on a surface along the slot. The grooves along the slot and the grooves on rib may mate with extensions on opposing sides of the expandable member to define a path by which the expandable member moves between expanded and retracted positions.

Abstract: In one embodiment, a wear band comprises a rotating element having a bore receivable on a tubular, the bore comprising first and second bore portions slidably receiving first and second sleeve bearings. Outer surfaces of the sleeve bearings slidably engage the bore portions and the bores of the sleeve bearings slidably engage the tubular. A first stop collar and a second stop collar may be received on the tubular to together straddle the rotating element and sleeve bearings to longitudinally secure the rotating element in a position on the tubular. The tubular may be included within a tubular string run into a borehole or into the bore of an installed casing, such as in casing while drilling. The rotating element provides stand-off between a tubular and the wall of a bore, reduces frictional resistance to longitudinal sliding and also to rotation of the tubular string within the bore.

Abstract: A steerable drilling apparatus includes a control system inside a cylindrical housing connected to a drill bit having radially-extendable pistons. A fluid-metering assembly directs a piston-actuating fluid into fluid channels leading to respective pistons. The control system controls the fluid-metering assembly to allow fluid flow to selected pistons, causing the actuated pistons to temporarily extend in the opposite direction to a desired wellbore deviation, thereby deflecting the drill bit away from the borehole centerline. An upper member in the fluid-metering assembly can be moved to stabilize, steer, and change TFA within the drill bit. The control system and drill bit are connected so as to facilitate removal to change the drill bit's steering section and cutting structure configuration or gauge simultaneously. The apparatus may incorporate a fluid filter module mounted to the control system. The pistons may incorporate auxiliary cutting elements to provide near-bit reaming capability.

Abstract: Provided are a system and method for calculating and selecting a convergence path based on cost. In one example, the method includes identifying multiple geometric convergence paths that each provides a convergence solution from a defined bottom hole assembly (BHA) location to a target path. A total monetary cost is calculated for each of the geometric convergence paths using an offset cost based on a distance of the geometric convergence path from the target path, a curvature cost based on an amount of curvature of the geometric convergence path, and a time cost based on an estimated amount of time needed to drill the geometric convergence path. The total monetary costs of the geometric convergence paths are compared and one of the geometric convergence paths is selected based on the total monetary cost of that geometric convergence path relative to the total monetary costs of the other geometric convergence paths.

Abstract: A cleanup device having a first board having a first edge, a second board having a first edge, a first hinge attached to the first edge of the first board and the first edge of the second board, an aperture defined by a portion of the first edge of the first board and a portion of the first edge of the second board, a first plate slidably attached to the first board, wherein the first plate is movable from a first, open position where the aperture is open to a second, closed position where the first plate extends over at least a portion of the aperture, and wherein a top surface of the first board is movable towards a top surface of the second board to form a V-shaped surface for directing dirt or soil off of the first board and the second board.