Abstract: The present disclosure relates to cutting elements incorporating polycrystalline diamond bodies used for subterranean drilling applications, and more particularly, to polycrystalline diamond bodies having a high diamond content which are configured to provide improved properties of thermal stability and wear resistance, while maintaining a desired degree of impact resistance, when compared to prior polycrystalline diamond bodies. In various embodiments disclosed herein, a cutting element with high diamond content includes a modified PCD structure and/or a modified interface (between the PCD body and a substrate), to provide superior performance.

Abstract: A cutting element assembly includes a sleeve, a lining extending a distance axially from an end of the sleeve, and an inner cutter. The inner cutter has a cutting end, wherein the cutting end extends a depth from a cutting face, a side surface, and a body, wherein the body is at least partially disposed within the sleeve, and wherein the side surface of the cutting end interfaces with an interfacing surface of the lining.

Abstract: An improved rope socket for downhole operations, capable of separating within the wellbore to permit removal of upper components and attached wireline, while lower components including an uphole-facing fishing neck remain attached to a tool string or fish within the wellbore. Also, an improved drop bar for actuating a release mechanism of the improved rope socket. The improved drop bar includes wheel assemblies having integrated axles to provide a stronger axle capable of offset placement along the circumference of the drop bar.

Abstract: An inductive coupler includes a first transceiver electrically coupled to a first coil through a first tuning circuit. The inductive coupler may also include a second transceiver electrically coupled to a second coil through a second tuning circuit, where the second coil is positioned substantially concentric with the first coil.

Abstract: Implementations described herein include a hoisting device and method for handling, coupling and recovery of tubular members such as drill string components. The hoisting device has a self-energizing gripping means configured to releasably engage a drill string component. In one aspect, the self-energizing gripping means can be operable to increase at least one of a radial biasing force and a contact friction force applied to a drill string component, causing the gripping means to increase the overall gripping force applied to the component with minimal effort exerted by a hoisting device operator.

Abstract: Methods and apparatuses for preventing the uncontrolled release of fluid materials from a well string during decoupling are provided. The apparatus includes an elongated body having an internal passage running along the longitudinal axis thereof, wherein the internal passage is configured to conform to the outer perimeter of a portion of a pipe and coupling of a well string such that fluid released from the coupled pipes during a decoupling operation is controllably redirected downward.

Abstract: A tool for making up and breaking out a drill string at an exit side of a bore. The tool includes a fixed vise and a moveable vise for torqueing a pipe joint, a roller assembly for threading and unthreading adjacent sections of pipe, and a retainer assembly to retain a detached pipe section. The components of the tool are mounted on a frame, which is pivotally connected to a hydraulic machine such as an excavator. Thus, the tool may be manipulated to remove and add sections of pipe to a drill string remote from the primary horizontal directional drill.

Abstract: Systems and methods are provided for aligning pressure drilling system equipment. According to such methods, a longitudinal axis of a shaft of the pressure drilling system is determined. An offset between the axis of the shaft and a longitudinal axis of a blowout preventer is determined. A first adjustment component is coupled with the blowout preventer. A second adjustment component is aligned relative to the first adjustment component based on the measured offset. The second adjustment component is coupled with the first adjustment component. A rotating control device is coupled with the second adjustment component such that an axis of the rotating control device corresponds with the axis of the shaft to account for the measured offset.

Abstract: An inner barrel assembly for use with a coring tool may include a sleeve located coaxially within an inner barrel in a telescoping manner. The core barrel assembly may also include a cap located above a top end of the sleeve when the inner barrel assembly is in an initial coring position. The cap may include a skirt having a portion extending downwardly from the cap. A coring tool including an inner barrel assembly and methods of forming an inner barrel assembly are also disclosed.

Abstract: Downhole drill pipe cutting is achieved by a free-falling sub carrying a shaped charge cutter and an ablative fluid cutter. Upon seating on a drill string flow bore orifice, fluid pressure is raised to detonate the shaped charge cutter. In the event the shaped charge cutter fails, pressure is further raised to effect a cut by fluid ablation.

Abstract: A borehole mill has blades that extend radially while moving along an inclined dovetail as a result of setting down weight on a mandrel. The blades extend axially beyond the end of the mandrel so that setting down weight disables a retainer that has the blades retracted for running in. Axial displacement of the blades along respective dovetails breaks a shear pin on a follower sleeve that is spring biased off a gage ring on the mandrel such that the spring stays compressed as long as set down weight is applied and once the mill is picked up the spring pushes the blades axially along a dovetail to the radially retracted position. The mill resumes its smallest dimension for pulling out of the hole.

Abstract: An apparatus can include a well treatment system that supplies a treatment fluid, a conveyance device and a well tool conveyed by the conveyance device. The well tool can include a perforator configured to form at least one hole in the wellbore tubular and a restrictor projecting from an outer surface of the well tool and adjacent to the perforator. A gap may separate the restrictor and the wellbore tubular. The well tool may also include a flow space that provides fluid communication between a location uphole of the restrictor and a location downhole of the restrictor. The flow space is sized to be restricted by particles in the treatment fluid. The restrictor at least restricts fluid flow through an annulus between the restrictor and the wellbore tubular, and the well tool diverts a substantial amount of the treatment fluid through an at least one hole formed by the perforator.

Abstract: An apparatus, fixed or recoverable to control a remote device includes a valve assembly having a cylinder, a piston dividing the cylinder into a first hydraulic chamber and a second hydraulic chamber, a spring to bias the piston toward the first hydraulic chamber, and a linkage to connect the piston to the remote device, a quick-vent valve assembly comprising an inlet connected to a hydraulic source, an outlet connected to the first hydraulic chamber, and a vent port, wherein the quick-vent valve assembly is configured to discharge fluid from the outlet to the vent when a pressure of the hydraulic source connected to the inlet drops below a threshold value, and a vent line connecting the vent port of the quick-vent valve assembly to a hydraulic accumulator.

Abstract: An assembly includes a first hub having a body and an end surface, first and second openings defined in the body and a plurality of segmented collets positioned around the body. A locking mandrel is operatively coupled to the body, wherein the locking mandrel is adapted to engage the plurality of segmented collets, and a latching/release mechanism is positioned at least partially within the first and second openings defined in the body, wherein the latching/release mechanism is adapted to be positioned in a first position wherein the locking mandrel is in an unlocked and loaded position and in a second position wherein the locking mandrel is released and engages the plurality of segmented collets so as to couple the first hub to a second hub.

Abstract: A method of separating a tubular element, comprising providing a tubular element having an inner and an outer surface, a circumference of said outer surface, and a first end and a second end; radially surrounding said tubular element with an explosive material, wherein said explosive material is capable of generating a high-velocity plasma jet in response to an activation signal, and wherein said explosive material comprises an electrically conductive layer; transmitting said activation signal to said explosive material; generating said high-velocity plasma jet; and separating said tubular element into a first portion comprising said first end and a second portion comprising said second end when said high-velocity plasma jet penetrates said outer surface of said tubular element and exits said inner surface of said tubular element.

Abstract: A well drop releasing device has a housing attachable to a well tubing. The device has a well drop carrier to carry a well drop. The well drop carrier is linearly movable to move the well drop from an exterior the well tubing into an interior the well tubing and release the well drop in the interior of the well tubing.

Abstract: A method of forming multiple inclusions into a subterranean formation can include initiating the inclusions into the formation, the inclusions extending outwardly in respective multiple azimuthal orientations from a casing section, and flowing fluid into each of the inclusions individually, thereby extending the inclusions into the formation one at a time. A system for initiating inclusions outwardly into a subterranean formation from a wellbore can include a casing section having multiple flow channels therein, each of the flow channels being in communication with a respective one of multiple openings formed between adjacent pairs of circumferentially extendable longitudinally extending portions of the casing section. Another system can include a casing section, and an injection tool which engages the casing section and selectively directs fluid into each of the inclusions individually, whereby the inclusions are extended into the formation one at a time.

Abstract: The invention concerns a radially expandable metal tubular element having on its outer surface a series of spaced apart annular sealing modules. This element is noteworthy in that each sealing module comprises two annular metal abutments between which there are inserted an annular seal and two anti-extrusion rings, the seal being positioned between the two anti-extrusion rings and the two metal abutments being secured against the outer surface of the said tubular element, in that the two anti-extrusion rings are made in elastically and plastically deformable material and are in one or two parts, and in that the two anti-extrusion rings and/or the seal comprise at least two opposite facing bevelled surfaces capable of sliding relative to one another under the effect of axial movement of the said seal so as to cause outward radial displacement of one of the anti-extrusion rings or at least one of the two parts thereof.

Abstract: An example downhole tool includes a wellbore isolation device that provides a plurality of components including one or more first components and one or more second components. Each component is made of a degradable material that degrades when exposed to a wellbore environment, and the one or more first components degrades at a first degradation rate while the one or more second components degrades at a second degradation rate that is slower than the first degradation rate.

Abstract: A downhole plug for use in oil and gas well completions made of aluminum, dissolves in natural wellbore fluids, has a dissolvable seal made of aluminum split rings or a degradable elastomer, has a backup pump out ring, and may be provided to the well site as an interchangeable parts kit for adaption to the well's requirements, to provide an interventionless plug in a well.

Abstract: An insert for a slip of a downhole tool including a base, a first button, a second button, and a connecting member. The first and second buttons extend from the base and are configured to engage an inner diameter surface of a tubular. The connecting member extends from the base and is positioned between the first button and the second button.

Abstract: In some aspects, a downhole assembly is provided that can include a window joint positioned within a tubular element and a bypass restrictor. The bypass restrictor can be positioned in an annulus between an outer surface of the window joint and an inner surface of the tubular element. The bypass restrictor can restrict the flow of a pressurized fluid via the annulus from a first end to a second end of a wiper plug.

Abstract: A flow control device can include water in a chamber, the chamber having a variable volume, a flow restricting member which displaces in response to a change in the chamber volume, and a biasing device which influences a pressure in the chamber. A method of controlling flow of steam in a well can include providing a flow control device which varies a resistance to flow in the well, the flow control device including a chamber having a variable volume, water disposed in the chamber, and a biasing device. The biasing device influences the chamber volume. Another flow control device can include water in a chamber, the chamber having a variable volume, a flow restricting member which displaces in response to a change in the chamber volume, and a biasing device which reduces a boiling point of the water in the chamber.

Abstract: The present application describes methods and systems for a tool with a new check valve. The check valve may include a piston sleeve that is configured to move towards the proximal end of the tool to seal restrictive ports in a center of the tool responsive to creating a force on the piston sleeve. In embodiments, the movement of the piston sleeve may be counter to the flow of fluid through an inner diameter of the tool, such that the tool may be resettable and repeatable based on fluid flow and/or pressure differentials and not based on drag force through an inner diameter of the tool.

Abstract: A sleeve apparatus having a longitudinal axis and an interior further includes a tubular having a plurality of ports providing a length of fluidic access between the interior and an exterior of the tubular, the length measured with respect to the longitudinal axis; and, a sleeve disposed within the tubular and configured to move longitudinally with respect to the longitudinal axis. The sleeve further has a plurality of apertures misaligned with the plurality of ports in a closed condition of the sleeve apparatus and at least substantially aligned with the plurality of ports in a fully open condition of the sleeve apparatus, and a plurality of non-apertured sections aligned with the plurality of ports in the closed condition. A longitudinal shifting distance of the sleeve to move the sleeve apparatus from the closed condition to the fully open condition is less than the length of fluidic access.

Abstract: A tubular actuation system includes a housing and an activatable sleeve including a first assembly having a first radially movable seat, a second assembly having a second radially movable seat, and an insert disposed between the first and second assemblies. The activatable sleeve is movable longitudinally from a first position to a second position, and from a second position to a third position within the housing.

Abstract: An insulated electrical conductor (MI cable) may include an inner electrical conductor, an electrical insulator at least partially surrounding the electrical conductor, and an outer electrical conductor at least partially surrounding the electrical insulator. The insulated electrical conductor may have a substantially continuous length of at least about 100 m. The insulated electrical conductor may have an initial breakdown voltage, over a substantially continuous length of at least about 100 m, of at least about 60 volts per mil of the electrical insulator thickness (about 2400 volts per mm of the electrical insulator thickness) at about 1300° F. (about 700° C.) and about 60 Hz. The insulated electrical conductor may be capable of being coiled around a radius of about 100 times a diameter of the insulated electrical conductor. The outer electrical conductor may have a yield strength based on a 0.2% offset of about 100 kpsi.

Abstract: A well system includes a work string extendable into a wellbore, and a pump that pumps a fluid into an annulus defined between the work string and the wellbore. A flow-activated motor is coupled to the work string and has a housing that receives the fluid pumped into the annulus. The flow-activated motor further includes a driveshaft rotatably positioned within the housing and a plurality of rotor vanes coupled to the driveshaft, wherein the driveshaft rotates as the fluid flows through the housing and impinges on the plurality of rotor vanes. A rotating agitator tool is coupled to the driveshaft such that rotation of the driveshaft correspondingly rotates the rotating agitator tool. The rotating agitator tool engages and loosens debris in the wellbore while rotating, and the debris is entrained in the fluid and flows through the flow-activated motor and subsequently to a surface location for processing.

Abstract: Methods and apparatus for cultivating a surface of a wall of a subterranean well bore, conduit or cable by scraping and furrowing the surface using a string hoistable shaft carrying a flexible arrangement of a laterally extendable and retractable arcuate engagement linkage dragging a cutter and scraper member, wherein said engagement linkage arcuately engages and aligns the cutter and scraper member during one or more scraping engagements: along said surface and longitudinal to a well axis to form and use said furrow, across said surface and transverse to said well axis using a filament linkage to form and use said furrow, or along and across said surface and longitudinal and transverse to said well axis to form and use a lattice of said furrows, separating a plane of the surface into a plurality of planes that comprise separate surface regions, usable by an ancillary apparatus or a spreadable substance.

Abstract: A method for orienting a tubing string in a wellbore comprises lowering a tubular string within a casing string in a wellbore, engaging the tubular aligning tool with a casing aligning tool while lowering the tubular string, rotating the tubular string in response to engaging the tubing aligning tool with the casing aligning tool, rotationally aligning the tubular string opening with a casing string opening disposed through the casing string based on the rotating, and retaining the tubular string opening in an axial aligning and a rotational aligning with the casing string opening. The tubular string comprises: a tubular string opening and a tubular string aligning tool.

Abstract: A downhole kinetic energy storage system for wellbore completions is configured for installation downhole for extended periods of time, such as 10 year or more. The kinetic energy storage system receives power from a low power source, which can be due to a “power bottleneck” to the downhole location such as inductive coupling, optical fiber, downhole energy harvesting, and/or subsea wellhead configurations. The system stores the available low-power as rotational energy in a flywheel and then when demanded converts the rotational energy into electrical energy at a temporary power level exceeding the low power source. The temporary high power energy is used for wellbore completion applications such as actuating a flow control or other downhole valve.

Abstract: A method of removing a flexible line deployed between an offshore platform and a subsea structure, where the platform has a landing deck on which the flexible line is installed, the landing deck facing away from the platform towards an installation side. The method comprises: decoupling a topside end of the flexible line from the landing deck; lowering the topside end from the landing deck to the sea bed using a platform mounted winch, and detaching the winch from the topside end; moving the platform in a direction away from the installation side and positioning an installation vessel on the installation side; lowering a recovery line from the installation vessel and attaching an end of the recovery line to the topside or subsea end of the riser; raising the attached topside or subsea end onto the installation vessel from the seabed using the recovery line; and recovering the flexible line onto the installation vessel, whereupon the platform can be moved back to an operating position.

Abstract: A high-pressure, high-temperature tieback system including a production casing tieback tool consisting of a ratchet-latch sleeve disposed in a recessed portion of an annular extension of increased wall thickness of the production casing tieback tool and a production casing mudline hanger disposed about the production casing tieback tool. The production casing tieback tool is configured to directly engage the production casing mudline hanger. The ratchet-latch sleeve is configured to directly engage a threaded axial segment of a tubular other than the production casing mudline hanger.

Abstract: A cutting tool adapted to be deployed into a well casing for cutting through casing strings comprises a nozzle for directing a jet of an abrasive slurry at the wall of a well casing to sever the well casing and a mechanical locking arranged provided above the nozzle, said locking arrangement comprises radially expandable means selectively engageable with an inner wall of the well casing within which the tool is deployed, to prevent axial and/or rotational movement of the tool in the well during cutting operations.

Abstract: A method for simulating fluid flows in a petroleum reservoir to improve final oil recovery. The fluid comprises water, hydrocarbon, and surfactant components. The method comprises a flash step for calculating compositions via two stages. A first stage comprises a first flash to determine first compositions of the water, oil and gas phases and is performed by omitting the surfactant component in the fluid. A second stage comprises a second flash to determine a microemulsion composition of the microemulsion phase.

Abstract: A chemical injection mandrel for injecting chemicals into a Lower Tertiary well includes a chemical injector disposed on an exterior surface of a mandrel. The chemical injection mandrel connects to the production tubing such that the chemical injector portion of the chemical injection mandrel is disposed in the annulus between the production tubing and wellbore at or near the bottom of the hole. A floating production storage and offloading unit on the surface of the water may include a chemical injection pump that injects chemicals downhole via a chemical fluid line that runs in the annulus between the production tubing and the wellbore. The chemical fluid line connects to the chemical injector portion of the chemical injection mandrel and delivers chemicals to the interior passageway of the mandrel of the chemical injection mandrel where the chemicals mix with the production flow directed to the surface.

Abstract: Examples of the present disclosure relate to systems and methods for fracturing systems that maintain a substantially constant pressure differential between a first pressure zone and a second pressure zone.

Abstract: A dedicated hydraulic line for transmission of a signal device capable of generating one or more unique signals to one or more tools within a subterranean well. Each tool can be equipped with a reader device for receiving signals from and transmitting signals to the signal device. Each reader device can control operation of the tool associated therewith if the reader device is programmed to respond to signals received from the signal device. Hydraulic fluid used to operate the tool can be conveyed via the dedicated hydraulic line or a separate hydraulic line. A separate hydraulic line can be used to reset the tool. Where the tools include sliding sleeves, the tools can be used to hydraulically fracture subterranean environs at spaced apart locations along a well bore in any desired sequence and without removing the tools from the well during the fracturing process.

Abstract: The disclosure pertains to methods for completing a well may comprise lowering a coiled-tubing in the well thus forming an annulus between the casing and the coiled-tubing, pumping down said annulus a treatment fluid above the fracturing pressure of the formation while also pumping fluid through the coiled tubing. The methods may also comprise monitoring in real-time the bottom hole pressure and increasing the pump rate through the coiled-tubing if an increase of bottom hole pressure is observed.

Abstract: A system including a rotary isobaric pressure exchanger (IPX) configured to exchange pressures between a first fluid and a second fluid, and a motor system coupled to the hydraulic energy transfer system and configured to power the hydraulic energy transfer system.

Abstract: A centralized power system including at least one engine having a plurality of discharge connectors; a plurality of articulating power connectors, each articulating power connector comprising a first end connected to a corresponding discharge connector, and a second end connectable to at least one piece of oilfield equipment thereby supplying power from the at least one engine to the oilfield equipment.

Abstract: An electrically powered hydraulic fracturing system having pumps for pressurizing fracturing fluid, piping for carrying fracturing fluid, and vibration reducing equipment for use with the piping. The vibration reducing equipment includes helical coils that support the piping. The coils are made of a wire rope made of strands of steel cable twisted together. Grooved fittings are provided on some piping connections, and which allow pivoting between adjacent fluid conveyance members. Swivel joints are strategically located in the piping which allow rotational flexing between adjacent sections of the piping; thereby attenuating vibration in the piping but without stressing the piping.

Abstract: A burst plug assembly for use in the fluid port of tubular fracturing tools to provide erosion resistance. The assembly has a body with an annular side wall and a closing wall closing the central bore of the annular side wall. A choke insert is retained in the central bore of the body to line the inner surface of the central bore. A groove in a face of the closing wall circumscribes a core in the bottom wall, and is sized and located so that a largest dimension of the core is no greater than a diameter of the inner bore of the choke insert, such that when a prescribed threshold hydraulic pressure level of the treatment fluid is applied to the closing wall the core disengages from the closing wall along the groove in a bursting action and passes through the inner bore of the choke insert.

Abstract: A gas and solids separation system is disclosed to separate gas and solids in a subterranean wellbore thereby preventing the gas and solids from interfering with down-hole equipment. The system includes shrouds and diverters that directs the gas away from the intake of the down-hole artificial lift equipment and also utilizes solids collection chambers and shields which separate and trap solids.

Abstract: A device for use in recovery of gas trapped by fluid and suspended solids in a gas or oil well includes a body defining a cavity with a cap at its upper end and an opening for entry of fluid at its bottom end. A lower valve controls fluid flow into, and an upper valve controls flow out of, the cavity. Pressurized gas pushes downward on fluid in the cavity in a compression stroke which closes the lower valve and opens the upper valve. Gas is exhausted from the cavity during an exhaust stroke. An effluent line allows exit of the fluid and suspended solids during the compression stroke. A probe line provides electrical power to a pair of probes for initiating and halting entry of the stream of pressurized gas into the cavity.

Abstract: A geo-steering method for drilling a formation penetrated by multiple wells. The method comprises computing a stratigraphic target formation window, computing a target line utilizing an instantaneous formation dip angle correlated to offset well data from an offset well. The method further comprises calculating a target window from actual drilling data overlaying the target window over the stratigraphic target formation window to drill on the target line, identifying target deviation from target line using overlaid windows, generating a target deviation flag when the overlaid results differ above or below the stratigraphic target formation window or user inputted target deviation flag parameters, wherein the target deviation flag stops drilling by the rig. The method performs another actual survey, creating a new window, starting drilling, creating a new target window, overlaying the two windows and monitoring for target deviations, repeating the process until target depth is reached.

Abstract: A drilling system can include a mud motor arranged in a drill string and a turbine shaft operatively coupled to a drill bit. The drilling system can also include a plurality of turbine stages axially arranged along a portion of the turbine shaft, a measure-while-drilling (MWD) tool operatively and communicably coupled to the mud motor, and a pressure sensor configured to detect pressure pulses generated by the mud motor and generate data signals corresponding to the pressure pulses. Further, the drilling system can include an electronics module communicably coupled to the pressure sensor and configured to process the data signals and thereby calculate a rotational speed of the mud motor. Furthermore, the drilling system can include a communications module communicably coupled to the electronics module and configured to transmit signals indicative of the rotational speed of the mud motor to a surface location.

Abstract: Systems, methods, and devices for evaluating proper cement installation in a well are provided. In one example, a method includes obtaining acoustic cement evaluation data points and processing the acoustic cement evaluation data points using a solid-liquid-gas model to assign at least some of the acoustic cement evaluation data points to a material of solid, liquid, or gas in an annulus of the wellbore behind the casing. The solid-liquid-gas model includes a tight solid-liquid-gas model in which a gas threshold range is not directly adjacent to a liquid threshold range and/or a solid-liquid-gas model that considers flexural attenuation when a pulse-echo-derived acoustic impedance is below an evanescence point.

Abstract: A retrievable tool for steering through an earth formation includes a first tool assembly and a tilted antenna attached to the first tool assembly. The tool also includes a second tool assembly attached to the first tool assembly and a tilted antenna attached to the second tool assembly. The first tool assembly attaches to the second tool assembly so that the antennas are tilted in predetermined directions. The tilted antennas are transmitter antennas or receiver antennas. Each tool assembly is a tubular cylinder with a longitudinal axis running the length of the cylinder, wherein the tubular cylinder has two ends, each end including a rotational attachment mechanism. The tool assemblies attach to each other through their rotational attachment mechanisms. The rotational attachment mechanism may be a screw-on mechanism, press-fit mechanism, or welded mechanism.

Abstract: Apparatus, systems, and methods may include a magnetic dipole transmitter to be located in a ranging well. A voltage measurement device can include a plurality of probes where each probe is to be located on one of a target well, the ranging well or a surface of a geological formation comprising the ranging well and the target well. A controller coupled to the voltage measurement device calculates a distance or relative direction between the target well and the ranging well based on a voltage difference between the plurality of probes. The distance/direction can be used to control drilling operations. Additional apparatus, systems, and methods are disclosed.