Abstract: Method for controlling the direction of a drilling device which drills a hole into a ground wherein a hammering and rotatable bit (3) is used as the drilling bit and the device comprises coupled with the bit (3) a hammering device (2) behind the bit (3) and a drill arm which is potentially related to it wherein the rear part (15) of the hammering device or the drill arm locates in the drilled hole or inside a casing tube (1) which covers the drilled hole in a free space so that there is space for the mentioned rear part (15) to move in the direction of the radius of the drilled hole and that the location of the bit (3) in the ground during the drilling is observed on the grounds of the data received from the position sensors which indicate the location of the bit (3), characterized in that in the method the direction of the drilling is steered by adjusting only the position of the mentioned rear part (15) in relation to the center line (C) of the drilling by organizing a support, which is deviated from the ce

Abstract: An earth boring bit has a bit body with a depending bearing pin, a cone rotatably mounted on the bearing pin, a seal gland between the cone and the bearing pin, and a seal assembly located in the seal gland. The seal assembly includes an annular metallic spring encircling the bearing pin. The spring has a geometric center line that extends in a circle around the bearing pin. The spring is elastically deformable in radial directions relative to the center line. An elastomeric layer is located on an exterior side of the spring and is biased by the spring against a surface of the seal gland.

Abstract: An example rolling cutter assembly includes a rolling cutter disposable within a cutter pocket defined in a drill bit, the cutter pocket including a receiving end, a bottom end, and a sidewall extending between the receiving and bottom ends. The rolling cutter provides a substrate having a first end with a diamond table disposed thereon and a second end arrangeable within the cutter pocket at or near the bottom end. A bearing element is disposable within the cutter pocket at the bottom end and engageable with the second end of the rolling cutter as the rolling cutter rotates about a central axis.

Abstract: An insert to convert a conventional rotary drill bit to a rotary steerable bit for a rotational directional drilling system. The insert comprises a cylindrical body adapted to be arranged within an intermediate space of the drill bit for receiving drilling fluid from a drill string and selectively directing the drilling fluid to nozzles of the drill bit. The insert may be rotatable and connected to a geostationary platform. Alternatively, the insert may be fixated in the drill bit, combined with a flow diverter connected to a geostationary platform. The insert is suitable to be introduced in the drill bit at a drilling location, including remote locations and off-shore rigs.

Abstract: Techniques and systems to reduce deflection of a riser extending from offshore platform. The riser may be coupled to a seafloor and may experience movements due to, for example, currents. A riser restraint device may be utilized to reduce these movements of the riser. This riser restraint device may be coupled to the seafloor. This coupling of the riser restraint device may aid in allowing the riser restraint device to reduce movement of the riser and, thus, reduce deflection of the riser.

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

Abstract: An interlock pipe joint includes a first and second tubular member. In some embodiments, an interrupted thread box and pin make up the interlock pipe joint. In other embodiments, a stepped interrupted thread box and pin make up the interlock pipe joint. In other embodiments, a twist-lock box and pin make up the interlock pipe joint. In some embodiments, an external or internal bushing is provided. In a method of operation, the first tubular member is inserted into the second tubular member by an axial insertion followed by a rotation to lock the pipe joint.

Abstract: A flexible reamer housing includes a tubular central portion including a tool bay with an aperture to allow a reamer cutter arm within the tool bay to move radially outward through the aperture, and tubular first and second auxiliary portions arranged toward opposite ends of the central portion. The first and second auxiliary portions each include a first stiffness that is less than a second stiffness of the central portion.

Abstract: A modular carousel for holding a drill pipe segment in a drilling rig includes a central support having a top end and a bottom end, and a top plate removably coupled to the top end of the central support, the top plate including a top plate slot sized to receive an upper end portion of the drill pipe segment. A breaker plate has a breaker plate slot sized to receive an intermediate portion of the drill pipe segment, and a coupler assembly is configured to removably attach the breaker plate to the bottom end of the central support. A base plate is coupled to the breaker plate by an extension support, the base plate including a cup sized to receive a bottom end portion of the drill pipe segment.

Abstract: A pipe handling apparatus and method for using the pipe handling apparatus is described. The pipe handling apparatus can be used by putting a boom of the pipe handling apparatus in a nesting position. The boom of the pipe handling apparatus is pivotally mounted to a base and at least one arm. In the nesting position, a pivot point between the at least one arms and the boom is moved within an elongated slot of the boom and the length of the at least one arm is simultaneously adjusted.

Abstract: A tubular handling system has a trough with two exterior channels and an interior channel disposed between the two exterior channels. The two exterior channels and the interior channel are disposed along a longitudinal length of the trough and are configured to support at least one tubular. The tubular handling system also has a set of exterior kickers configured to move the tubular from one of the exterior channels to the interior channel and from one of the exterior channels to a position out of the trough. The tubular handling system has an interior kicker configured to move the tubular from the interior channel to one of the exterior channels.

Abstract: Techniques and systems to reduce contact of a cable with a top drive. A cable guide may be mounted to one or more bails supporting the top drive and may operate to extend a distance between a cable passing along a length of the top drive. The cable guide may include both an upper guide assembly and a lower guide assembly. Each of the upper guide assembly and the lower guide assembly may both be coupled to one or more bails supporting the top drive in a serial manner.

Abstract: An apparatus for detecting potential kicks in a well is provided. In one embodiment, the apparatus includes a drill string positioned in a well, a mud circulation system coupled to supply drilling mud to the drill string, and a mud analyzer. The mud analyzer includes a sensor that is positioned along a drilling mud return path closer to a wellhead assembly installed at the well than to a mud tank of the mud circulation system, and the mud analyzer enables identification of a potential formation kick based on data acquired by the sensor. Additional systems, devices, and methods are also disclosed.

Abstract: Embodiments of the present disclosure relate to a drilling fluid system that includes a conduit configured to convey a fluid from a first sub-system of the drilling fluid system to a second sub-system of the drilling fluid system, an ultrasonic measurement system configured to determine a flow rate of the fluid in the conduit, and a controller configured to receive feedback from the ultrasonic measurement system and to adjust one or more operating parameters of the drilling fluid system based at least on the feedback.

Abstract: A telemetry apparatus for use in a well can include multiple segments, the segments comprising at least one buoyancy control device, at least one telemetry device, and at least one articulation device that controls a relative orientation between adjacent ones of the segments. A method of communicating in a subterranean well can include installing at least one telemetry apparatus in the well, the telemetry apparatus comprising a telemetry device and a buoyancy control device, and the telemetry device communicating with another telemetry device at a remote location. A well system can include at least one telemetry apparatus disposed in a wellbore, the telemetry apparatus comprising multiple segments, the segments including at least one buoyancy control device and at least one telemetry device.

Abstract: There is provided a locator configured for coupling to a workstring for locating a wellbore feature, The locator includes a protrusible member, a chamber, a hydraulic fluid supplying passage, and a hydraulic fluid supply source. The protrusible member is moveable, relative to the workstring, and biased for disposition, relative to the workstring, in an extended position. In the extended position, the protrusible member is engageable with the wellbore feature. The first chamber is disposed in fluid pressure communication with the protrusible member, and has a volume configured to change correspondingly with a change in position of the protrusible member such that expansion of the first chamber corresponds with an extension of the protrusible member and such that contraction of the first chamber corresponds with a retraction of the protrusible member. The hydraulic fluid supply source is fluidly coupled to the first chamber via the hydraulic fluid supplying passage.

Abstract: A stabilizer system articulates at least one blade independently of an extendable blade for a through tubing mill. The stabilizer can be actuated with flow, pressure or set down weight. A piston responds to flow or pressure from the surface and an elongated member can cam out the stabilizer with set down weight on the extendable blades.

Abstract: A downhole tool may include a bridge plug releasably coupled to a casing cutting tool. The bridge plug may be set within a wellbore and the casing cutting tool may be used in a milling or perforating operation during a single downhole trip of the downhole tool. A method for using a downhole tool may include setting the bridge plug in a wellbore and performing a casing cutting operation during a same downhole trip. The casing cutting tool may be a section mill and a section milling operation may be performed before or after uncoupling the bridge plug from the section mill while downhole. The section milling operation may remove an entire portion of casing within a region of the wellbore for receiving a cement plug. The casing cutting too may be a perforation tool and perforating may be used to remove portions of casing.

Abstract: A jarring tool includes a spring and a hydraulic piston cylinder arrangement for controlling the release of a mandrel to initiate a jarring force. The tool includes an adjustment mechanism for adjusting the minimum amount of an upward pulling force required to release the mandrel. The adjustment mechanism includes an axially adjustable trigger sleeve that cooperates with a dog clutch surrounding the mandrel.

Abstract: A device is for stabilizing a well head which includes a well base arranged on a seabed. The well base includes at least a support column, and a first portion of a conductor casing being encircled by the support column, an annulus encircling the first conductor-casing portion being filled with cement, and a second portion of the conductor casing projecting in an elastically flexible manner up from the first conductor-casing portion. A method is for stabilizing a well head which includes a well base arranged on a seabed.

Abstract: An offshore well system for a subsea well. The system includes a floating platform, an external riser and an internal riser nested within the external riser. A external riser tension device tensions the external riser. The drilling system also includes a surface wellhead system that includes a wellhead, a collet, and a flange assembly. The wellhead, collet, and flange assembly are assembled to establish a common bore for receiving the top of the internal riser. A gasket located between the top of the internal riser and an inner shoulder of the flange assembly seals between the wellhead system and the top of the internal riser. The surface wellhead system also retains the internal riser in tension with the wellhead, the internal riser extending above the wellhead into the collet.

Abstract: The present invention relates to a downhole expandable tubular to be expanded in a well downhole from a first outer diameter to a second outer diameter to abut against an inner face of a casing or borehole, the downhole expandable tubular having an outer face and a longitudinal extension and comprising at least one first circumferential edge and at least one second circumferential edge provided on the outer face and spaced apart in the longitudinal extension, wherein a sealing element and a split ring-shaped retaining element are arranged between the first and second circumferential edges, the split ring-shaped retaining element forming a back-up for the sealing element and wherein the split ring-shaped retaining element has more than one winding, so that when the expandable tubular is expanded from the first outer diameter to the second outer diameter, the split ring-shaped retaining element partly unwinds. Furthermore, the present invention relates to an annular barrier.

Abstract: Wellbore isolation is used for a tubing string in a well. A first plug is held by a first temporary retention in a bore of a housing disposed on the tubing string and is sealed in the bore with a first seal. A second plug is also held in the bore by a second temporary retention and is sealed in the bore with a second seal. The first and second seals seal a space in the bore between the plugs. Both plugs can be of a dissolvable material. An uphole end of the first plug facing away from the space can have a non-dissolvable coating, while a downhole end of the second plug facing away from the space can have a non-dissolvable coating. The first plug releases in the bore when an uphole pressure is applied in the tubing string, and the second plug then releases after the first plug.

Abstract: Systems and methods that produce bremsstrahlung radiation may facilitate the setting of a settable composition. For example, a method may include providing a settable composition in a portion of a wellbore penetrating a subterranean formation, a portion of the subterranean formation, or both; conveying an electron accelerator tool along the wellbore proximal to the settable composition; producing an electron beam in the electron accelerator tool with a trajectory that impinges a converter material, thereby converting the electron beam to bremsstrahlung photons; manipulating the trajectory of the electron beam in a radial direction, an axial direction, or both of the wellbore with a rastoring device of the electron accelerator tool; and irradiating the settable composition with the bremsstrahlung photons.

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: Pressure perforated well casing collars have at least one pressure perforation groove cut to a consistent depth in an a sidewall of the well casing collar with sidewall bottom material at a bottom of the groove. The sidewall bottom material ruptures at a predetermined fluid pressure greater than a burst pressure rating of plain casing joints connected to the well casing collars to assemble a well casing string.

Abstract: A float valve for positioning downhole within a wellbore as part of a drill string. The float valve has an outer hollow housing for connection to and location between an upper and lower sections of the drill string. A flap valve is located at least in part within the outer hollow housing to allow or disallow flow of fluid and/or objects through the outer hollow housing via the float valve. A sliding sleeve is located at least in part within the outer hollow housing, to translate at least in part within the outer hollow housing, such that in a first position the sliding sleeve is clear of the flap valve, and in a second position the sliding sleeve retains the flap valve open to allow the flow therethrough.

Abstract: A multi-function diverter tool is disclosed that allows positive-indication opening and closing of the tool in a downhole environment.

Abstract: A remotely deployed untethered device for actuation of a downhole application. The device may be equipped with inductive measurement capacity for interaction with a downhole well architecture. Such capacity affords the ability to trigger an actuation remotely at a site specific location in the well without further intervention relative surface equipment.

Abstract: A heater includes a heater housing extending along a heater axis; a fuel cell stack assembly disposed within the heater housing and having a plurality of fuel cells which convert chemical energy from a fuel into heat and electricity through a chemical reaction with an oxidizing agent; a first medium conduit fixed relative to the heater housing and in fluid communication with the fuel cell stack assembly, the first medium conduit including a first medium conduit shelf extending laterally from the first medium conduit; a second medium conduit fixed relative to the heater housing and in fluid communication with the fuel cell stack assembly, the second medium conduit including a second medium conduit shelf extending laterally from the second medium conduit; wherein the fuel cell stack assembly is supported on the first medium conduit shelf and the second medium conduit shelf.

Abstract: An enclosure installed on oil well equipment to capture escaping gas emissions and recover them using intermittent use of a vapor recovery unit which evacuates the gas that slowly accumulates in the enclosure to a custody line for commercial or treatment elsewhere.

Abstract: Systems and methods for monitoring, calculating, and/or optimizing the consumption of fuel in operating motorized equipment in well site operations or other jobs are provided. In one embodiment the methods comprise: calculating a set of fuel consumption rates for one or more engines at a job site as a function of a speed of each engine, a hydraulic horsepower load to be provided by each engine, and an external parasitic load to be provided by each engine; identifying one or more operating speeds for the one or more engines during an operation at the job site based at least in part on the set of fuel consumption rates for the one or more engines; and operating the one or more engines at the one or more operating speeds during an operation at the job site.

Abstract: A method of installing a sealing ring onto a wire wrap screen comprising: providing the sealing ring, wherein the sealing ring has an initial inner diameter greater than the outer diameter of an end of the wire wrap screen; reducing the inner diameter of the sealing ring, wherein the reduced inner diameter of the sealing ring is less than the outer diameter of the end of the wire wrap screen; heating the sealing ring; positioning the heated sealing ring over the end of the wire wrap screen; and allowing the sealing ring to decrease in temperature. Another method comprises positioning at least two sealing rings adjacent to a cut-out section of the wire wrap screen.

Abstract: A low-debris low-interference semi-solid well perforator having selectively variable free volume and method for providing such is disclosed according to one or more embodiments. The perforator may include a charge tube holding an independently floating axial stack of selectively variable divider segments, each having one or more concavities formed in upper and lower sides. The segments are arranged so that concavities of adjacent segments form sockets, into which shaped charges are located. The segments provide support to minimize deformation of shaped charge cases yet provide less than 360 degrees circumferential contact about the shaped charges to form selectively variable voids for collecting debris and spall resulting from detonation. The voids and floating segments attenuate detonation shock interference. A debris guard prevents debris from entering the wellbore. Relieving slots in the debris guard attenuates transmission of shock interference through the debris guard.

Abstract: A perforating gun includes a carrier, an explosive charge positioned within the carrier, a detonator positioned within the carrier, and a switch positioned within the carrier. The detonator detonates the explosive charge when the detonator receives power. The switch actuates between at least a first position and a second position. The switch transmits power to the detonator when the switch is in the first position, and the switch transmits power to a pyrotechnic device when the switch is in the second position. The pyrotechnic device detonates or deflagrates when the pyrotechnic device receives power.

Abstract: A method and apparatus for improving the production efficiency of a well and preventing gas lock. The apparatus is a downhole pump and comprises a barrel, a reciprocating plunger and a body having a plurality of inlet valves. The apparatus does not require outlet valves. The body and inlet valves are positioned above the barrel and plunger, thus eliminating gas lock. Fluids enter the body through the valves and, during upstrokes of the plunger, are forced up the tubing string to the surface equipment. Modularity of the components permits pump components to be changed as the productivity of the well fluctuates and also allows production of more fluids with a smaller casing. The invention prevents gas lock by permitting gasses to escape between a sliding valve and a valve rod connected to the plunger. Additionally, an exit valve sealably engages the valve rod, which forms an aperture. During operation of the pump, the gasses escape through the aperture in the valve rod and rise up the tubing string.

Abstract: A method and apparatus for operating a plunger lift system in a well can include: opening a control valve and allowing a plunger to rise to a top of the well; determining an actual rise time of the plunger based on a time it takes the plunger to rise to the top of the well; using actual rise time of the plunger and a target rise time calculating adjustments to the afterflow time or close time; and allowing the afterflow time to pass before closing the control valve and keeping the valve closed for the close time. The methods are repeated, each time calculating a new adjusted afterflow time or adjusted close time to incrementally alter these times.

Abstract: A direct drive motor-based walking beam pumping unit includes a base; a support is arranged at the upper end of the base; a walking beam is arranged at the upper end of the support; a horsehead is arranged at a first of the walking beam; a lifting rope is arranged on the horsehead and a beam hanger is arranged on the lifting rope; a balance weight is arranged at a second end of the walking beam away from the horsehead; a barrel is arranged at the upper end of the base; a direct drive motor is arranged at the upper end of the barrel.

Abstract: The use of coal fields as subsurface bioreactors for producing sustainable methane gas from terrestrial sources of biomass is described. Microbial presence is determined for a target coal formation, and tracers are injected to determine permeability, porosity, volume, and minimum and a maximum material injection rates. At least one injection well and at least one circulation well effective for generating an injection rate between the minimum and maximum injection rates are provided for injecting a solution of biodegradable materials into the coal seam. A chosen quantity of biodegradable materials is allowed to be digested, fermented and converted by microbial action within the coal seam. Methane gas is extracted through producing and injecting wells, although pumping will enhance gas recovery.

Abstract: Compositions and methods for triggering an exothermic reaction of an exothermic reaction component. A method includes the steps of mixing the exothermic reaction component in an aqueous solution to achieve a pre-selected solution pH, where the aqueous solution operably delays triggering of the exothermic reaction upon reaching a pre-determined temperature of a hydrocarbon-bearing formation; disposing the exothermic reaction component within the hydrocarbon-bearing formation; applying microwaves to the exothermic reaction component, where the microwaves are operable to trigger the exothermic reaction of the exothermic reaction component; and generating heat and gas in situ by the exothermic reaction to increase pressure and temperature of the hydrocarbon-bearing formation proximate the exothermic reaction component.

Abstract: A hydrocarbon resource recovery system may include an RF source, and an RF antenna assembly coupled to the RF source and extending laterally within a wellbore in a subterranean formation for hydrocarbon resource recovery. The RF antenna assembly may include first and second tubular conductors, and a dielectric isolator coupled between the first and second tubular conductors to define a dipole antenna. The hydrocarbon resource recovery system may include solvent injectors within respective laterally extending wellbores extending transverse and above the RF antenna assembly and configured to selectively inject solvent into the subterranean formation adjacent the RF antenna assembly.

Abstract: A well fracturing component has a steel body with at least one passage and a connector for connecting the body to a source of pressurized frac fluid containing particulates for injecting into a well. An epoxy-based primer layer bonds to a side wall of the passage. A siloxane topcoat layer bonds to the primer layer. The topcoat layer has a greater thickness than the primer layer. The topcoat layer has less hardness than the primer layer and loss hardness than the body.

Abstract: The present invention relates to a method, a system (1) and tool(s) (300, 2, 3) for single trip through drill pipe proppant fracturing of subterranean formations (130) surrounding oil and/or gas production wells (100).

Abstract: Systems and methods for extracting minerals from an underground mineralization zone located below the surface at an oil and gas drilling site. The system includes a vertical drilling means for drilling a vertical bore extending from the surface at the oil and gas drilling site into the mineralization zone, a second horizontal drilling means for drilling at least one horizontal production bore into the mineralization zone. The first horizontal drilling means and the second horizontal drilling means are configured to return material from the mineralization zone to the surface where the mineral content of the material is analyzed and a separator separates minerals, waste and drilling mud from the material. The method includes steps of drilling a horizontal assessment bore, analyzing assessment material for a desired mineral, drilling a horizontal production bore, producing production material containing the desired mineral, and separating the desired material from waste and drilling mud.

Abstract: An apparatus, rock drilling rig and method for rock drilling includes a turning device for moving a drilling tool around longitudinal axis of the tool. The turning movement is controlled by an alternating turning system so that direction of turning movement is continuously reversed to first and second turning directions. The turning angle of the tool is restricted and a safety system (is configured to monitor the operation and to ensure that a predetermined turning angle is not exceeded.

Abstract: Apparatus and methods for monitoring and processing wellbore data are disclosed. An integrated digital ecosystem comprises an applied fluid optimization specialist and one or more sensors communicatively coupled to the applied fluid optimization specialist. The applied fluid optimization specialist receives data relating to performance of subterranean operations from the one or more sensors and interprets the data received. The applied fluid optimization specialist then regulates the performance of subterranean operations based on the interpretation of the data received.

Abstract: The present disclosure relates to an inspection assembly (10) for inspecting the interior of a pipe (12). The inspection assembly (10) comprises a sensor assembly (20) adapted to receive a sensor signal and a housing (22) within which the sensor assembly (20) is at least partially arranged. The inspection assembly (10) comprises a seal (24) at a first housing end (31). Moreover, the inspection assembly (10) is adapted to assume a transport condition in which the sensor assembly (20) is positioned in a first position in the housing (22) and in which the seal (24) is closed. The inspection assembly is further adapted to assume an inspection condition in which the inspection assembly (20) is positioned in a second position, closer to the first housing end (31) as compared to the first position, and in which the seal (24) is open.

Abstract: A system and method for producing fluid from a subterranean wellbore that includes an electrical submersible pump (“ESP”) system and a receptacle. The ESP system is landed in the receptacle while sensing the presence of the ESP system with respect to the receptacle. The ESP system includes a motor, a pump, a monitoring sub, and a stinger on the lower end of the pump. A sensor on the receptacle detects the position of the stinger within the receptacle, and provides an indication that the stinger has inserted a designated length into the receptacle so that a fluid tight seal is formed between the stinger and receptacle.

Abstract: The present disclosure provides the printed circuit board assembly suitable for operating downhole at high temperatures. The printed circuit board assembly has a ceramic circuit board with a plurality of chips installed on it. At least one of the chips has an aluminum nitride or a silicon nitride substrate. In some of the chips, aluminum nitride is used as the oxide layer in a Si-on-Insulator configuration. In other chips, integrated circuits are fabricated on a substrate made from aluminum nitride, silicon nitride, silicon carbide, or sapphire.

Abstract: A telemetry system with a plurality of controllers and telemetry systems, where the controllers are configured to obtain information from one or more sensors and transmit that information on one or more of the plurality of telemetry systems. The configuration of a controller may be changed so as to change which information is transmitted on a given telemetry system.