Abstract: A horizontal directional drilling system. The system has a pilot drill and an exit side drill, with a drill string extending between them. A backreamer is positioned between the drills to enlarge a borehole. The pilot drill pulls and rotates the backreamer. The exit side drill adds segments to the product pipe and pushes the product pipe into the enlarged borehole. The exit side drill is equipped with a rotational disconnect. The disconnect is engaged to allow torque transfer between a motor and a spindle when adding segments to the product pipe. The disconnect is disengaged to prevent torque transfer between the motor and the spindle when pushing the product pipe into the enlarged borehole.

Abstract: A large diameter injection water well is drilled using a drilling derrick and rotary drilling techniques after snubbing in and drilling a short distance with drilling mud, a temporary drilling header is installed below the blowout preventers. Extending downward from the temporary drilling header is a drop pipe with a valve on the lower end thereof. Drilling pipe with attachments on the lower end thereof, are lowered into the drop pipe with the valve closed. After sealing to the drilling pipe, the valve is opened and the drilling pipe and attachments are lowered to the bottom of the well for the normal drilling operation. Thereafter, the drilling pipe and attachments are removed reversing the process of retracting into the drop pipe and closing the valve before removing the seal from the drilling pipe.

Abstract: An improved typelog alignment for automated or interactive geosteering may use multi-stage penalized optimization.

Abstract: Systems and methods for controlling an orientation of a tool face for a drilling rig. Multiple methods are provided that use estimated tool face orientation along with measured parameters to determine inputs to the drilling rig such that, after activation, the tool face has a desired orientation.

Abstract: Systems and methods for subterranean drilling operations comprising: adjusting a wellbore parameter; measuring a time interval between adjustment of the wellbore parameter and a resulting change at a bottom hole assembly of a drill string; using the measured time interval and determining resistance in the wellbore; and modeling the resistance to form a friction model of the wellbore.

Abstract: A drilling system includes a drill string, a plurality of sensors, and a computing system. The drill string includes a downhole motor. The sensors are coupled to the drill string. The computing system is coupled to the sensors. The computing system is configured to compute, based on measurements provided by the sensors, a motor stall index, and to determine, by comparing the motor stall index to a motor stall threshold, whether the downhole motor has stalled. The computing system is also configured to, responsive to a determination that the downhole motor has stalled, adjust operation of the drill string to restart the downhole motor.

Abstract: A method for estimating the efficiency of hole cleaning of a well-bore during drilling operations includes (a) selecting at least one feature of the drilling operation for monitoring; (b) receiving, from a sensor, data regarding the at least one feature; (c) comparing the data to a predetermined condition for the at least one feature; (d) defining an event when the data meets the predetermined condition; (e) assigning a weight to the event based on a duration of the event; and (f) estimating an efficiency of the hole cleaning based on the event and the weight of the event. The at least one feature being selected from the list consisting of: hole angle, circulation, tight spot, static hole, and bit hydraulics.

Abstract: Control valves can allow a well operator to steer a drill string. An exemplary control valve can include a valve body with an axial bore and a radial orifice in fluid communication with the axial bore, wherein flow passing through the axial bore passes through the radial orifice and into a piston flow channel to be in fluid communication with a piston bore to exert pressure against a piston movable within the piston bore, the piston being coupled a steering pad for applying force against the wellbore wall. A rotary valve element is disposed within the axial bore and including an actuation flow channel, wherein the rotary valve element is rotatable with respect to the axial bore to change flow through the actuation channel and the radial orifice to modify fluid pressure within the piston flow channel that is exerted against the piston.

Abstract: A hazardous material storage system includes a drillhole extending into the Earth and including an entry at least proximate a terranean surface. The drillhole includes a substantially vertical portion, a curved portion, and a horizontal portion that includes a hazardous waste repository formed within a first portion of the horizontal portion of the drillhole, the hazardous waste repository vertically isolated, by a rock formation, from a subterranean zone that includes mobile water, and a safety runway formed within a second portion of the horizontal portion exclusive of the hazardous waste repository and adjacent the curved portion, the safety runway defined by a particular length.

Abstract: A method can include receiving data for a borehole trajectory in a formation, a length of pipe, and a bottom hole assembly that includes a mud motor and a bit; generating a sequence for operation of the mud motor using a model of at least the bit, where the sequence includes a sliding mode and a rotary mode for drilling the borehole in the formation a distance less than or equal to the length of pipe; and drilling the borehole according to the sequence.

Abstract: The invention concerns a computer implemented method for underbalanced drilling. In one embodiment, the method includes determining a plurality of gas injection rate versus bottom hole pressure curves for a plurality of liquid injection rates for a specified minimum and maximum gas injection rate and a minimum and maximum liquid injection rate. Next, the method determines a set of four interception curves including a minimum motor equivalent liquid rate interception curve, a minimum vertical liquid velocity intercept curve, a minimum horizontal liquid velocity intercept curve, and a maximum motor equivalent liquid rate intercept curve for a specified minimum and maximum mud motor rate range and a minimum horizontal and vertical annulus velocity.

Abstract: An automation system for a drilling rig includes a processor and a computer memory in communication with the processor and storing computer executable instructions, that when implemented by the processor cause the processor to perform functions that include receiving as a function of time at least one of a) at least one surface operating parameter and b) at least one downhole operating parameter. The processor further may at least one of filter and smooth the at least one surface operating parameter and the at least one downhole operating parameter to generate processed data. The processor may generate a measure of drilling energy from the processed data and determine a minimum of the measure of the drilling energy, and calculate a target value of the at least one of the at least one surface operating parameter and the at least one downhole operating parameter.

Abstract: A downhole intelligent reamer controller detects the difference between rotary drilling and sliding drilling, responds appropriately and quickly to multiple changes between rotary drilling and sliding drilling that may occur several times each stand of pipe. Additional controls prevent deployment of reamer members at inappropriate times such as when drilling out cement, testing, and running in and out of the wellbore. In one embodiment, a separate modular control sub is disclosed that may be utilized with and/or removably secured to an expandable reamer and/or other types of downhole tools.

Abstract: A drilling assembly and method of drilling a wellbore is disclosed. The drilling assembly includes a steering device having a tilt device and an actuation device. A first section and a second section of the drilling assembly are coupled through the tilt device, wherein the first section is attached to a drill bit. The actuation device includes an electromechanical actuator and causes a tilt of the tilt device to cause the first section attached to the drill bit and the drill bit to tilt relative to the second section. The wellbore is drilled using the drill bit. The electromechanical actuator is actuated to tilt the tilt device to cause the first section attached to the drill bit and the drill bit to tilt relative to the second section and to maintain the tilt geostationary while the drilling assembly is rotating to form a deviated section of the wellbore.

Abstract: A wellbore completion comprises a borehole extending into a subterranean formation, a first portion of the borehole disposed within at least one production zone of the subterranean formation, and one or more completion zones within the first portion of the wellbore. The first portion maintains a high dog-leg severity throughout the first portion, and the one or more completions are configured to allow for fluid communication between an interior of the borehole and the subterranean formation.

Abstract: The present disclosure relates to a tool for a closed reduction of a fracture. The tool includes at least: a winding portion having a winding shape; a support extending from the winding portion in a normal direction relative to a plane of the winding shape; and a handle extending from the support in the normal direction, and configured to be gripped.

Abstract: The disclosed embodiments include systems and methods to improve downhole drilling. A representative system may include a geostationary portion (e.g. a valve assembly) and a turbine coupled to the geostationary portion to cause counter-rotation of the geostationary portion relative to a drillstring in a default state. A generator that is also operable to act as a motor is coupled to the turbine, and is also coupled to a controller and an energy that may harness any excess energy generated by the turbine when the turbine is able to counter-rotate the geostationary portion at a faster rate than needed to maintain the geostationary portion in a rotationally static condition relative to the wellbore.

Abstract: An example apparatus for controlling the direction of drilling a borehole includes a housing and a radially offsetable drive shaft at least partially within the housing. The apparatus may further include one or more pusher extendable from the housing. The one or more pusher may be extendable in response to a radial offset in the offsetable drive shaft with respect to a longitudinal axis of the housing.

Abstract: A drilling apparatus and a method for releasing rods stuck in surrounding ground use a torsional device for releasing the drilling assembly and induce centrifugal forced vibrations and bending vibrations in the drilling rods, facilitating the release from positions stuck inside the drilled hole. The apparatus allows the available power of the motor drilling device to be fully applied for generating periodic forced vibrations useful for detaching the drilling rods stuck in the surrounding ground.

Abstract: A method for drilling a wellbore through a subterranean formation includes rotating a drill string in the subterranean wellbore to drill. The drill string includes a rotary steerable tool or a steerable drill bit including a plurality of pads configured to extend radially outward from a tool body and engage a wall of the wellbore. Radial displacements of at least one of the pads are measured while rotating (e.g., drilling). A formation index is computed while drilling by processing the measured radial displacements, where the formation index is indicative of a strength or hardness of the subterranean formation.

Abstract: A new system for and a method of deploying a heat exchanger pipe. A bore hole is drilled from an access ditch location to a terminal ditch location using a piloted drill head powered via an umbilical attached to the piloted drill head. A casing is attached to the piloted drill head and disposed about the umbilical into the bore hole from the access ditch location to the terminal ditch location. At the terminal ditch location, the piloted drill head is removed from the casing and the umbilical and a heat exchanger pipe is attached to the umbilical. The umbilical is withdrawn from within the casing deployed in the bore hole to pull the heat exchanger pipe into the casing. The casing is then withdrawn from the bore hole leaving the heat exchanger pipe in the bore hole.

Abstract: A rigid chain actuator (201) including a tool body (203) having a bore (204) with a chain (206) at least partially disposed in a housing (211) coupled to the tool body. Additionally, the rigid chain actuator includes a chain extension/retraction mechanism to extend the chain from the housing into the bore and recoil the chain from the bore into the housing. Furthermore, the chain may translate a force onto at least one wellbore tool through the bore.

Abstract: A drill string steering system includes a motor and a rotary valve body disposed in a tool body. The motor includes a motor shaft coupled to the motor and extending within a central bore of the tool body. The motor shaft has a downhole engagement portion that includes a first splined surface. The rotary valve body includes a disk-shaped component and a valve shaft coupled to the disk-shaped component and extending uphole of the disk-shaped component. The valve shaft includes a second splined surface engageable with the first splined surface for rotation of the motor shaft to be imparted to the rotary valve body.

Abstract: A system and method of automating a slide drilling operation comprising a plurality of tasks is described, in particular, reducing stored torque within a drill string that extends within a wellbore that includes storing, using a computing system, a first predetermined workflow to reduce stored torque within the drill string, and a second predetermined workflow to reduce stored torque within the drill string, wherein the first predetermined workflow comprises instructions to vertically move the drill string in first and opposing second directions; and wherein the second predetermined workflow comprises instructions to rotate the drill string in a first direction.

Abstract: An anchor delivery system includes both a straight and curved drill guide along with a flexible drill, a flexible obturator and a flexible anchor inserter. The curved drill guide has a distal tip with approximately a 15° bend from the primary axis of the drill guide. Both the drill and the obturator have a reduced diameter section to improve flexibility during passage through the curved drill guide. Additionally, a surface of the inserter shaft has a laser cut pattern which permits flexing of the inserter around the inner diameter of the curved drill guide.

Abstract: A drilling system and method of drilling a wellbore. The drilling system includes a tubing, an orientation device affixed to the tubing, a drilling sub having a housing having a first section and a second section, wherein the first section is coupled to a movable element of the orientation device, a shaft disposed in the housing, the shaft coupled to the drive and to the drill bit, and a pivot member coupled to the first section and second section of the housing. The second section of the housing tilts relative to the first section of the housing about the pivot member when the orientation device is rotationally stationary to allow drilling of a curved section of the wellbore. Rotation of the housing via the orientation device reduces the tilt between the first section and the second section to allow for drilling of a straight section of the wellbore.

Abstract: A method is described for automated post-geosteering including receiving a pilot well log and a lateral well log with an initial lateral well path; performing automated post-geosteering to generate a corrected well path image; and displaying the corrected well path image on a graphical display. The method may be executed by a computer system.

Abstract: A method for constructing a wellbore includes drilling a wellbore along a trajectory using a bit; reaming the diameter of a portion of the drilled wellbore to enlarge a portion of the wellbore; and altering the trajectory of the bit by applying a lateral force to the enlarged diameter wellbore. Reaming the diameter of the portion of the drilled wellbore increases the dogleg of the wellbore.

Abstract: Remedial wellbore operations can be performed using metal material coated with a layer that is controllably activated to release the metal material downhole in a wellbore. At least a portion of the wellbore can be plugged or sealed using the metal material.

Abstract: A drilling system for forming a wellbore includes a drill string, a drill bit, and a circulation sub in the drill string. Manipulating the circulation sub forms a passage through a sidewall of the drill string; which diverts some of the drilling fluid flowing inside the drill string into the wellbore. Diverting some of the drilling fluid through the passage reduces the amount of drilling fluid flowing in the wellbore between the drill bit and circulation sub, and which optimizes equivalent circulating density of the drilling fluid. Included in an embodiment of the circulation sub is a cylinder that is indexed into set positions by engagement with a J-slot profile in a housing of the circulation sub. A sleeve in the sub is responsive to cylinder positions, and has a port that registers with a slot in the sub walls to form the passage.

Abstract: The present application describes a rapid burrowing robot (RBR) that can dig tunnels using ultra high temperature rotating plasma torches.

Abstract: A method of modifying a slide drill segment while implementing the slide drill segment includes receiving downhole data from a BHA during slide drilling of a slide drill segment. The method also includes calculating, based on the downhole data, a build rate and altering, while performing the slide drill segment, sliding instructions based on the build rate and the downhole data. The method also includes implementing the altered sliding instructions.

Abstract: A system, method and apparatus for a clutch for a well string can include a tubular member, a mandrel, a top sub and a bottom sub. A sleeve can be located between the tubular member and the mandrel. The sleeve has an engaged position wherein an inner sleeve spline is coupled to the mandrel spline, and a disengaged position wherein the inner sleeve spline is uncoupled from the mandrel spline. The sleeve has an outer sleeve spline that is coupled to the tubular spline in the engaged position and the disengaged position. A spring in the tubular member can bias the sleeve from one position to another position. The sleeve can be configured to be moved between the positions to overcome the spring bias.

Abstract: Angular position readings are obtained during rotation of an apparatus in a borehole, and angular rate readings are obtained over time of the rotation. The angular rate readings are adjusted based at least on the angular position readings. The angular position measurement does not require calibrated magnetometers or accelerometers to function. Additionally, a dynamic scale factor calculation for an angular rate gyroscope (ARG) allows the ARG to be used over a much wider operating range than without such a calculation. Finally, an integrated angular rate from the ARG calibrated for bias and scale factor fills in positional information between the magnetometers' zero crossings to deliver a high resolution hybrid angular position system capable of measuring precise angular position at high and irregular downhole rotation rates.

Abstract: A downhole drilling apparatus may comprise a rotatable body with various cutting elements connected thereto, some radially protruding therefrom, some radially extendable therefrom, and some revolvable relative thereto about a common axis. In operation, when the body is rotated, the radially protruding cutting elements may bore a generally cylindrical borehole. The radially extendable cutting elements may be extended during specific portions of the body's rotation to degrade certain areas of an inner wall of the borehole transforming it into a non-cylindrical borehole. At certain times, the revolvable cutting elements may be allowed to slide against the non-cylindrical inner wall while freely revolving to minimize disturbance to the borehole shape. At other times, revolution of these revolvable cutting elements may be restrained to ream the borehole back to a cylindrical shape.

Abstract: A first method of configuring a surface of a component exposed to fluid flow includes forming a plurality of protrusions on a surface, the plurality of protrusions separated by a plurality of channels, and depositing a coating on the surface to increase a coefficient of friction of the surface, the coating formed of a diamond-like carbon and having a wrinkled texture. A second method of configuring a surface of a component exposed to fluid flow includes forming a plurality of protrusions on a surface, the plurality of protrusions separated by a plurality of channels, and forming a plurality of nanotubes on the surface.

Abstract: A sidetrack assembly for forming a lateral wellbore includes a cutting device having a body having a passage, and a mill head configured to connect to the body so that an interior of the mill head and the body form a pressure chamber in fluid communication with the outlet passage. The mill head includes a first port in fluid communication with the pressure chamber, a second port in fluid communication with the pressure chamber, and a blade arranged on a face of the mill head. A whipstock connected to the cutting device includes a tubing having a first end removably inserted in the first port and the passage and a second end connectable to a downhole tool, an inclined surface for guiding the mill at a non-zero angle relative to a central axis of an existing wellbore, and an attachment section removably connecting the cutting device and the whipstock.

Abstract: A simulation system that receives a first plurality of inputs including at least one drilling parameter, at least one lithology parameter, and at least one earth-boring tool option; provides the first plurality of inputs to a cluster system; receives simulation data from the cluster system derived from a plurality of simulations of drilling operations utilizing the first plurality of inputs; analyzes the simulation data to generate a predictive algorithm for simulating drilling operations; receives a well plan including data related to a planned trajectory of a borehole; and utilizes the predictive algorithm to select a suitable earth-boring tool and suitable drilling parameters to achieve the planned trajectory of a borehole.

Abstract: A system and method for surface steerable drilling are provided. In one example, the method includes monitoring operating parameters for drilling rig equipment and bottom hole assembly (BHA) equipment for a BHA, where the operating parameters control the drilling rig equipment and BHA equipment. The method includes receiving current inputs corresponding to performance data of the drilling rig equipment and BHA equipment during a drilling operation and determining that an amount of change between the current inputs and corresponding previously received inputs exceeds a defined threshold. The method further includes determining whether a modification to the operating parameters has occurred that would result in the amount of change exceeding the defined threshold and identifying that a problem exists in at least one of the drilling rig equipment and BA equipment if no modification has occurred to the operating parameters. The method includes performing a defined action if a problem exists.

Abstract: A Rotary Steerable System (RSS) includes a flexible collar coupled therein or thereto that permits the stiffness of the RSS to be controlled and permits a desired turning radius to be achieved without sacrificing stability characteristics of the RSS. The flexible collar may be positioned between a steering section and the controller of the RSS. The parameters affecting the geometry, position and stiffness characteristics of the flexible collar and the RSS may be selected strategically to match the requirements of the particular wellbore being drilled. By selecting these parameters strategically, improvements may be achieved related to tool length, bending stiffness, bending stress, torsional stiffness, shear stress due to torsion and increased dogleg severity tolerance.

Abstract: Working an underground arcuate path around at least a portion of an obstacle with a casing extending into the underground arcuate path, connecting a rotating control device to the casing; and a Venturi device connected to the rotating control device.

Abstract: A system and method for surface steerable drilling are provided. In one example, the system receives toolface information for a bottom hole assembly (BHA) and non-survey sensor information corresponding to a location of the BHA in a borehole. The system calculates an amount of incremental progress made by the BHA based on the non-survey sensor information and calculates an estimate of the location based on the toolface information and the amount of incremental progress. The system repeats the steps of receiving toolface information and non-survey sensor information and calculating an amount of incremental progress to calculate an estimate of a plurality of locations representing a path of the BHA from a first survey point towards a second sequential survey point.

Abstract: A rotary steerable drilling system includes a collar, a drill bit, and a bit shaft connecting the drill bit to the collar. The bit shaft is coupled to the collar through a joint capable of transmitting a torque from the collar to the bit shaft and is swingable with respect to the collar around the joint. The system, further includes first eccentric wheel and second eccentric wheel coupled to the bit shaft and rotatable to swing the bit shaft with respect to the collar around the joint to change a drilling direction, a controller for controlling the first eccentric wheel and second eccentric wheel to harmoniously rotate such that the swing of the bit shaft substantially compensates rotation of the bit shaft, and an active stabilizer mounted on the bit shaft and capable of pushing the bit shaft to deviate to cause a lateral displacement and a tilt angle of the drill bit.

Abstract: In one or more embodiments, a system comprises a first (target) wellbore disposed in a formation, the first wellbore having a pressure imbalance therein causing an influx of formation fluids, a second (relief) wellbore disposed in the formation, a drill string disposed in the second wellbore, the drill string comprising a drill bit and a logging tool, and a wellbore ranging module comprising a processor and memory, the wellbore ranging module coupled to the drill string. The logging tool is configured to detect acoustic energy originating from the influx in the first wellbore and generate one or more signals associated with the detected acoustic energy. The wellbore ranging module is configured to receive, from the logging tool, the one or more signals associated with the detected acoustic energy and determine, using the received signals, a direction from the drill bit to the influx of the first wellbore.

Abstract: A system and method for casing drilling with a subsea casing drive adapted to engage at the outer circumference of the casing string, to impart a linear force and/or torque to the casing string, and such a subsea casing drive per se are disclosed. During drilling, the subsea casing drive is provided in a subsea unit further comprising a blowout preventer, a pressure control device and a mud pump with an outlet to a mud hose connectable to a surface vessel. The wellbore is drilled by driving the bottom hold assembly, BHA, and the casing string into the wellbore by the subsea casing drive, while discharging mud and cuttings via the mud hose and supplying mud to the BHA from the mud circulation system on the vessel via the landing string and casing string.

Abstract: An apparatus for measuring gravity acceleration of a drilling tool comprises sensors and a measurement circuit. The sensor comprises a three-axis gravity accelerometer, a reference measurement sensor and a temperature sensor. The three-axis gravity accelerometer measures acceleration component signals in three mutually orthogonal directions, and the reference measurement sensor generates a signal that varies with rotation and is not affected by vibration or shock to serve as a reference signal. The temperature sensor measures the temperature in the apparatus to compensate the temperature effect of the gravity accelerometers. The measurement circuit acquires output signals of the sensors and performs cross-correlation processing on the accelerometer components using the reference signal to extract gravity acceleration signals so as to eliminate centrifugal acceleration, vibration, shock and other interferences generated by rotation.

Abstract: A heading transfer unit may be used to transfer a heading from a surface base to a MWD tool. The surface base may have a master north finder to determine a heading. The heading may be transferred to the heading transfer unit, which is in turn transferred to the MWD unit. The heading on the heading transfer unit is transferred to the MWD tool.

Abstract: A plug deflector includes a body having a first end and a second end opposite the first end, a tool receptacle provided at the first end and defining an internal bore having a first coupling mechanism defined on the internal bore, at least one plug provided at the second end, and a deflector surface provided at an intermediate location between the first and second ends. A system includes a Y-block positioned within a multi-lateral wellbore at a junction of a first wellbore and a second wellbore extending from the first wellbore, the Y-block having a first leg fluidly coupled to the first wellbore and a second leg fluidly coupled to the second wellbore, and a plug deflector coupled to the Y-block.

Abstract: An actuator for use in a directional steering assembly includes an ultrahard insert positioned on a working face. The ultrahard insert is positioned along at least a portion of the perimeter of the working face. The ultrahard insert has a coefficient of friction less than a material of the remainder of the working face.

Abstract: A piston assembly may comprise a housing with a wall, and at least one chamber formed in the wall. A piston may be disposed within the chamber and at least one passageway may pass through the piston. At least one pin may be disposed within the passageway and attached to the chamber, and the piston may be free to translate relative to the pin.