Abstract: A method for operating a shale shaker to separate solids from a solids laden fluid, the shale shaker comprising a basket for holding at least one screen and a vibratory mechanism for vibrating the basket to an acceleration value, the method comprising the steps of monitoring the magnitude of the load of solids laden fluid in the basket and adjusting the acceleration value induced in the basket according to the magnitude of the load, wherein the acceleration is stepped down to a low acceleration value below a low load threshold.

Abstract: An apparatus includes a downhole tool for conveyance in a wellbore extending into a subterranean formation. The downhole tool includes a modular cartridge assembly that includes a chassis assembly within a housing and that includes a flow line and an electrical pathway. The modular cartridge assembly includes a first connector at a first end and a second connector at a second end. The first connector and the second connector are in fluid communication with the flow line and are further in electrical communication with the electrical pathway.

Abstract: A method for reducing friction between a coiled tubing and a wellbore includes: generating a periodic pressure wave; coupling the periodic pressure wave to a coiled tubing in a wellbore; and propagating the periodic pressure change in the coiled tubing wherein a friction force between the coiled tubing and the wellbore is reduced. The shape of the periodic pressure wave can be modulated to a form similar to that of a sinusoidal waveform.

Abstract: A fixed cutter drill bit including a bit body having a plurality of primary blades extending radially from a bit center area, wherein the bit center area includes a partial connection between at least two of the plurality of primary blades. The fixed cutter drill bit further including at least one cutter disposed on at least one of the blades. Additionally, a method of designing a fixed cutter drill bit includes modeling the fixed cutter drill bit, the fixed cutter drill bit including a plurality of primary blades extending radially from a bit center area, wherein the plurality of primary blades includes a plurality of cutters. The method further including determining a center of an innermost cutter on each primary blade, creating a partial connection between the primary blades, and outputting the model of the fixed cutter drill bit.

Abstract: A sonde, inline sonde, or inline sonde and carrier, configuration for use in troubleshooting a pipe and providing precise location of the problem includes a sonde carrier having a first end adapted to attach to a line and a second opposite end adapted to attach to a troubleshooting device. A sonde transmitter having a hollow core is mounted over a line or hose or inline with the sonde carrier between the first and second ends. The sonde carrier includes means for coupling first and second body portions of the carrier together and to a high pressure water line and cleaning nozzle.

Abstract: A dynamometer measures applied weight and torque at a running tool location and transmits the measured information to a drilling rig operator. The system includes a dynamometer stem having a bidirectional torque and weight sensor coupled inline to the drill string, and further coupled to the running tool, so that the dynamometer stem will measure an applied torque and weight at the running tool and produce a signal in response. The dynamometer stem communicatively couples to a receptor stem, so that the receptor stem may receive the signal from the dynamometer stem. The receptor stem couples inline to the drill string at a rotary table of the drilling rig, and further communicatively couples to a display located proximate to an operator of the drilling rig, so that the receptor stem may transmit the signal to the display. The display presents the signal in real time to the operator.

Abstract: A method for controlling a resonance enhanced rotary drill comprising a rotary drill bit and an oscillator for applying axial oscillatory loading to the rotary drill bit, the method comprising: controlling frequency (f) of the oscillator in the resonance enhanced rotary drill whereby the frequency (f) is maintained in the range (D2 Us/(8000 ?Am))1/2?f?Sf(D2 Us/(8000 ?Am))1/2 where D is diameter of the rotary drill bit, Us is compressive strength of material being drilled, A is amplitude of vibration, m is vibrating mass, and Sf is a scaling factor greater than 1; and controlling dynamic force (Fd) of the oscillator in the resonance enhanced rotary drill whereby the dynamic force (Fd) is maintained in the range [(?/4)D2effUs]?Fd?SFd[(?/4)D2effUs] where Deff is an effective diameter of the rotary drill bit, Us is a compressive strength of material being drilled, and SFd is a scaling factor greater than 1, wherein the frequency (f) and the dynamic force (Fd) of the oscillator are controlled by monitori

Abstract: The present invention relates to a coring system and a determining method that can determine whether accurate coring was achieved. A coring system according to the present invention includes: a coring part with a core to be filled with an object to be cored; a driving unit controlling upward/downward movement of the coring part; a rope connecting the coring part with the driving unit; and a tensiometer measuring tension in the rope.

Abstract: A method for optimizing drilling includes initializing values of a plurality of drilling operating parameters and drilling response parameters. In a computer, an initial relationship between the plurality of drilling operating parameters and drilling response parameters is determined. A drilling unit to drill a wellbore through subsurface formations. The drilling operating parameters and drilling response parameters are measured during drilling and entered into the computer. A range of values and an optimum value for at least one of the drilling response parameters and at least one of the drilling response parameters is determined in the computer. A display of the at least one of the plurality of drilling operating parameters and the at least one of the drilling response parameters is generated by the computer.

Abstract: The lower end assembly of a measurement while drilling tool is secured against shock and vibration while drilling through the use of a locking cuff, an abrasion ring and a locking nut. A mule shoe at a lower end of the assembly has a diameter sized to allow a pulser helix to pass. The locking cuff is installed on one end of the mule shoe. A poppet housing is attached to an end of the pulser helix opposite the mule shoe. An abrasion ring is received about the external diameter of the pulser helix and is received on a shoulder located between the pulser helix and the poppet housing. An externally threaded lower end of the locking nut is received within a mating threaded bore in the extended locking cuff so that a portion of the locking nut is located between the locking cuff and the poppet housing. Tightening the locking nut within the bore of the locking cuff acts to lock the lower end assembly with respect to the mule shoe.

Abstract: A method for managing a drilling operation, including generating, by a first sensor and a second sensor of a bottom hole assembly (BHA), a first time based data log and a second time based data log, respectively, representing a borehole parameter along a drilling trajectory, determining, by a computer processor of the BHA and during the drilling operation, a time shift by comparing the first time based data log and the second time based data log, where offsetting the first and second time based data logs by the time shift maximizes a correlation factor of the first and second time based data logs, and determining, within a pre-determined time period from generating the first and second time based data logs, a drilling speed based on the time shift and a pre-determined distance between the first sensor and the second sensor.

Abstract: Disclosed herein is a method of delineating a second wellbore from a first wellbore. The method includes, emitting acoustic waves from a tool in the first wellbore, receiving acoustic waves at the tool reflected from the second wellbore, and determining orientation and distance of at least a portion of the second wellbore relative to the tool.

Abstract: A method for reducing drill tubular vibrations includes: constructing a mathematical model the drill tubular having mass distribution, material stiffness and material damping; constructing an equation of motion of the drill tubular in one of a time domain and frequency domain; transforming the equation of motion into a modal domain equation of motion to provide a mode shape of the drill tubular at an eigenfrequency, the mode shape providing an amplitude at a position along the drill tubular; comparing the amplitude at the position along the drill tubular to a threshold amplitude value; modifying at least one of the mass distribution, material stiffness and material damping if the amplitude exceeds the threshold value; and iterating the above step until at least one of the amplitude of the latest mode shape at the position is less than or equal to the threshold amplitude value and a predetermined constraint limits the modifying.

Abstract: An arrangement having a piston configured to move along an axial pathway a rotating seal configured to seal an inside environment from an outside environment, the rotating seal configured to be acted upon by a pressure exerted from the piston, a differential pressure sensor measuring a pressure difference between a first fluid from the outside environment and a second fluid on the inside environment, a motor connected to the piston, the motor configured to actuate the piston to a position along an axial pathway and an electronic feedback control system connected to the motor, the electronic feedback system configured to interface with the differential pressure sensor and maintain a pressure generated by the piston onto the rotating seal to a desired pressure.

Abstract: A drill bit assembly for measuring reservoir formation properties comprises a bit head and a pin body, and an electrically insulated gap joint between two conductive parts of the drill bit assembly. The bit head has a cutting end and an opposite connecting end with an engagement section. The pin body comprises a connecting end with an engagement section. The pin connecting end is connected to the bit head connecting end such that the engagement sections overlap. The electrically insulating gap joint can fill a gap between the bit head and pin body engagement sections such that the bit head and pin body are mechanically connected together at the connecting ends but electrically separated. Alternatively or additionally, the pin body can have two pieces which are separated by an electrically insulating gap joint.

Abstract: Systems and methods for processing drilling data. One embodiment provides a method comprising building user-designed contexts (which can be designated as built-in contexts) for drilling structures. The method also comprises orchestrating module execution within the user-designed contexts. The method further comprises providing data from the user-designed contexts to such modules via an interface. Some methods include monitoring drilling data to detect events (for instance departure from a pseudolog) and orchestrating module execution responsive thereto. The method can include exposing the orchestration of the execution of the module instances as a service. Moreover, some embodiments provide extra-contextual application program interfaces. In addition, or in the alternative, some embodiments schedule the orchestration of the modules based on declarations related to the inputs and/or outputs of the modules.

Abstract: The invention relates to a method and apparatus for opening threaded joints of drilling equipment (6) by striking the drilling equipment (6) with the percussion device of a rock drilling rig (1) and by measuring vibration originating from the drilling equipment (6) during striking. In addition to vibration, measuring means (9) measure a parameter defining at least one additional condition, on the basis of which the decision to stop striking is made.

Abstract: Systems, devices, and methods for evaluating cuttings entrained in a downhole fluid in a borehole intersecting an earth formation. Methods may include using at least one sensor to produce information responsive to a reflection of an emitted wave from downhole cuttings in the borehole, wherein the information is indicative of a parameter of interest relating to the downhole cuttings; and processing the information using at least one processor to estimate the parameter of interest. Methods may include using the at least one acoustic sensor to produce corresponding information from each of a plurality of azimuthally distributed orientations about a bottom hole assembly (BHA); and using the at least one processor to estimate from the information from each of the orientations an azimuthal variation of the parameter of interest. The at least one sensor may include acoustic sensors, electromagnetic sensors, and/or optical sensors.

Abstract: A method of drilling a subterranean wellbore using a drill string comprising the steps of: a. injecting a drilling fluid into the well bore via the drill string and removing said drilling fluid from an annular space around the drill string (the annulus) via an annulus return line, b. oscillating the pressure of the fluid in the annulus, c. determining the wellbore storage volume and wellbore storage coefficient for each fluid pressure oscillation, d. using the wellbore storage volume and wellbore storage coefficient to determine the proportion by volume of gas and proportion by volume of liquid in the annulus during that pressure oscillation.

Abstract: A bottom hole assembly attached to a drillstring includes a main body including multiple electrical insulator sections along a length thereof, each of the electrical insulator sections configured to have a voltage difference generated there across, wherein a transmitting electrical insulator section having a voltage difference generated there across is configured to remain open, and wherein all remaining electrical insulator sections are configured to be electrically shorted there across.

Abstract: A technique facilitates evaluation of a tool, such as a drill tool. The technique comprises collecting tool data via a sensor on a given tool during use of that tool in a given operation, e.g. drilling operation. Additional data related to the tool is accumulated from a plurality of sources external to the tool. For example, data may be collected from both downhole sources and surface sources. Upon completion of the operation, the tool data is transmitted to the surface for processing on a processor system in combination with the data cumulated from sources external to the tool. The processing may be performed in real time as the tool data is received from downhole to enable a comprehensive diagnosis of tool health prior to retrieval of the tool to the surface.

Abstract: A managed bulk drilling system that employs a guide wire for ranging and crosswell telemetry. Some system embodiments include multiple drilling assemblies operating in the vicinity of a reference well that contains an electrical cable. The electrical cable is coupled to a surface control system. The control system uses the electrical cable as part of an antenna to receive uplink signals from the drilling assemblies and to broadcast down-link signals to the drilling assemblies. The uplink signals can include position data and the downlink signals can include individual steering commands to adjust the trajectories of each drilling assembly. The cable can also generate a guidance field for the drilling assemblies to detect and follow.

Abstract: Downhole drilling vibration analysis uses angular and linear motion data on a drilling assembly. During drilling operations, pairs of accelerometers measure the angular and linear motion of the drilling assembly. Processing circuitry is operatively coupled to the accelerometer pairs and is configured to determine type and severity of vibrations occurring during drilling based on the angular and linear motion data. Drilling operations can then be modified to overcome or mitigate the detrimental vibrations.

Abstract: A system and method to synchronize distributed measurements in a borehole are described. The system includes a plurality of wired segments coupled together by couplers and a plurality of nodes configured to measure, process, or relay information obtained in the borehole to a surface processing system, each of the plurality of nodes comprising a local clock and being disposed at one of the couplers or between couplers. The system also includes a surface processing system coupled to a master clock and configured to determine a time offset between the master clock and the local clock of an nth node among the plurality of nodes based on a downhole generated synchronization signal.

Abstract: An apparatus and method used to determine the density and other properties of a corrosive liquid, such as drilling mud. The apparatus uses at least two sensor elements with ceramic facings spaced a known vertical distance apart and inserted into the fluid. The differential pressure measurement provided by these sensors is used to calculate the density of the liquid. This density measurement is then reported in real-time to an operator.

Abstract: An inground isolator and associated method can provide an electrically isolated break in a drill string using electrical insulating members/isolators that are supported by a housing. During drill string operations, the isolators are subject only compressive forces responsive to both extension (pushing) and retraction (pulling) by the drill string. The isolators can be formed from an electrically insulating material such as a ceramic material. An interchangeable inground tool system is described which integrally serves to provide an electrically isolating gap in the drill string.

Abstract: In one embodiment, a radio-frequency identification device for use in a wellbore includes a housing made of a polymer; and an antenna disposed in the housing. The polymer may be selected from the group consisting of an elastomer, a plastic, a rubber, a thermoplastic elastomer, and combinations thereof. The RFID device may also include a fill material disposed in the housing.

Abstract: Rock strength is estimated during drilling using a rate of penetration model or a modified mechanical specific energy models. The rock strength estimate can be used in conducting further drilling, for example by a drilling system. Drilling parameters may be altered as a result of determining rock strength, for example to avoid undesirable trending fractures, such as extensive vertical fractures.

Abstract: Temperature sensing devices and methods for determining downhole fluid temperature at a drill string in a borehole while drilling are disclosed. The device includes a temperature sensor capable of detecting and measuring rapid temperature changes and may be used to sense the temperature of fluid inside or outside the drill string. In addition, the device includes a thermal conductor that receives and secures the temperature sensor; the thermal conductor is in turn received and secured in a thermal insulator that provides a thermal barrier. In an embodiment, the device is disposed in a channel within an outer diameter of the drill string such that the device is protected from the side wall of the borehole and drilling fluid and cuttings can pass through the channel without becoming packed around the temperature sensor.

Abstract: The invention provides a system and method for facilitating oilfield operations utilizing auditory data. In one embodiment, the present invention generates one or more auditory mapping structures whereby oilfield data may be mapped to sounds. The present invention provides at least one computer generated selection tool through which the user may select one or more portions of displayed oilfield data for auditory enhancement. Once the user has indicated an area of interest using the selection tool, the present invention may identify the oilfield data displayed within the outlined area of interest, identify auditory data associated with the displayed oilfield data utilizing one or more auditory mapping structures, and emit at least a portion of the identified auditory data to enhance the user's understanding of the displayed oilfield data.

Abstract: A drilling system and associated systems and methods for monitoring, controlling, and predicting vibration of a drilling operation. The vibration information can include axial, lateral or torsional vibration of a drill string.

Abstract: This disclosure is drawn to methods, systems, devices and/or apparatus related to power control in applications over long cables. Specifically, the disclosed methods, systems, devices and/or apparatus relate to power control that considers the maximum power available at the end of a long cable (or from a battery) to a load over a broad range of load conditions. Some example systems may include a power supply located at the Earth's surface and a power converter coupled to the power supply via a cable having a first end coupled to the power supply and a second end coupled to the power converter. Some example power converters may be configured to measure the power being consumed by the electrical load in the well, and adjust operating parameter(s) of the electrical load based, at least in part, on the maximum power available at the second end of the cable.

Abstract: Planning and/or drilling wellbores. At least some of the various embodiments are methods including: receiving data indicative of position of a first wellbore; reading data indicative of position of an offset wellbore; reading data indicative of a fracture diameter for the offset wellbore; calculating a first positional uncertainty of the first wellbore; calculating a second positional uncertainly of the offset wellbore taking into account the data indicative of position and the data indicative of fracture diameter; and generating a value indicative of proximity of the positional uncertainties.

Abstract: A robot system, including one or more robots which are provided to a first area where an entry by a person is restricted, and configured to perform a first work which includes one or more steps in the first area, a controller configured to control an operation of the one or more robots, and a visitor detector configured to detect a visitor to the first area.

Abstract: A bias unit having a support body in use to be integrated with a drilling assembly and rotatable therewith for drilling a borehole penetrating a geological formation. A pad is pivotally connected to the support body proximate to the leading edge of the pad. A spring-driven push rod is positioned and preloaded to engage the pad, proximate to the trailing edge of the pad, and to urge the pad outward from the support body to contact the borehole wall during drilling.

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

Abstract: Systems and methods for using very small devices, “McNano devices,” to facilitate and enhance operations in the oilpatch. This abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure and is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims, 37 C.F.R. 1.72(b).

Abstract: A system for containing electronics positioned in a downhole tubular. The system includes a pressure housing, a rigid end piece, a compliant end piece, an inner tubular member, one or more annular standoffs, and a chassis. The pressure housing is supported within the downhole tubular. The rigid end piece and the compliant end piece are fixedly coupled within opposing ends of the pressure housing. The inner tubular member is disposed within the pressure housing and has opposing ends. One of the opposing ends is coupled to the rigid end piece, and the other of the opposing ends is free to move relative to the compliant end piece. The chassis is disposed within the inner tubular member and houses the electronics. Each standoff is disposed between the inner tubular member and the pressure housing and includes at least one radially extending portion compressed therebetween.

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

Abstract: A downhole sensing assembly for sensing motor parameters of a downhole motor positionable in a wellbore penetrating a subterranean formation is provided. The downhole motor has a stator and a rotor rotatable within the stator. The sensing assembly includes at least one rotor extension operatively connectable to the rotor and movable therewith, at least one marker positionable about the rotor extension, and at least one motor sensor positionable about a downhole tool and operatively coupled to the marker to detect movement of the marker whereby motor parameters, such as rotational speed of the motor, are detectable.

Abstract: A system is provided for communicating within a borehole using controlled vibrations. A movement mechanism uses mechanical energy provided by a mechanical energy source to enable translational movement of a first surface relative to a second surface to allow the first surface to repeatedly impact the second surface to produce a plurality of vibration beats. The vibration beats will occur whenever the mechanical energy is provided by the mechanical energy source at one of at least three impact levels. A vibration control mechanism selectively controls an amplitude of the plurality of vibration beats to encode information therein. The amplitude of a vibration beat is selectively controlled by regulating the impact of the first surface and the second surface to one of the at least three impact levels.

Abstract: A method and a system may be provided. The system may include: a drilling pipe that comprises an inner space; a telemetry system, arranged to (a) sense drilling information about an underground drilling process that is executed by the system, and (b) transmit the drilling information to an entity that is located outside the drilling pipe; a rechargeable battery arranged to provide power to at least one telemetry module of the telemetry system; and a controller, arranged to control a provision of power to the at least one telemetry module and to control a charging of the rechargeable battery. Wherein the at least one telemetry module, the rechargeable battery and the controller are shaped and sized to be positioned within the inner space of the drilling pipe. The battery and controller can also be mounted in the drilling collar.

Abstract: The present invention relates to glycerol based drilling fluids. In particular, the invention relates to drilling fluids comprising a 95-20 volume % glycerol/water solution capable of stabilizing water-sensitive formations during drilling and the use of such solutions for drilling a well having water-sensitive formations.

Abstract: A data acquisition module comprising a base sized and configured for disposition within a shank of a drill bit bore and an extension protruding therefrom having electrical contacts on an exterior surface thereof for connection to electrical contacts on an interior surface of a sub secured to the bit shank. A drill bit equipped with a data acquisition module, a bottom hole assembly including a drill bit bearing a data acquisition module operably coupled to a sub secured to the drill bit, and a method of transferring data from a data acquisition module carrying a data acquisition module to a sub secured to the drill bit.

Abstract: A bottom hole assembly for a drill string has a mud motor and a mandrel. The motor has a rotor driven by drilling fluid flow, and the rotor defines a bore for passage of fluid flow and/or conductors. The mandrel has a bore for passage of the conductors and/or fluid flow, and rotation of the mandrel rotates a drill bit. A shaft and universal joints transfer the drive of the rotor to the mandrel. To pass the conductors from a sonde uphole of the motor to electronics disposed with the mandrel and/or to conduct fluid flow, inner beams dispose in a bore of the shaft to seal at the ends of the shaft coupled to the first and second universal joints. Each beam has an internal passage for the conductors and/or fluid flow. One of the universal joints and inner beams compensate for eccentricity in motion of the rotor, while the other second universal joint and inner beam compensate for a bend in the downhole assembly.

Abstract: Apparatus including a sensor-containing body is disposable within a flowbore of a downhole tool. The apparatus also comprises an adjustable engagement mechanism that is coupled to the body. The engagement mechanism has a first position that allows the body to move longitudinally through the flowbore, and a second position that prevents movement of the body relative to the flowbore.

Abstract: The present invention provides apparatus and methods for controlled steering. One embodiment of the invention provides a bit body comprising a trailing end, a pilot section, and a reaming section. The trailing end is adapted to be detachably secured to a drill string. The pilot section is located on a leading, opposite end of the bit body. The reaming section is located intermediate to the leading and trailing ends. The pilot section comprises at least one steering device for steering the pilot section of the bit body, thereby steering the entire bit body. Another embodiment of the invention provides a wellsite system comprising a drill string; a kelly coupled to the drill string; and a bit body as described above. Another embodiment of the invention provides a method of drilling a curved borehole in a subsurface formation.

Abstract: A drill pipe (1), particularly for a drill string, has at least one electrical conductor (4, 7, 8, 9) and an inner pipe (2) which is arranged inside the drill pipe (1). The drill pipe (1) and the inner pipe (2) are spaced at a distance to one another in sections, wherein the drill pipe (1) and inner pipe (2) bound a hollow space (3). At least one electrical conductor (4, 7, 8, 9) is arranged on one outer side of the inner pipe.

Abstract: An apparatus for communicating a signal downhole includes a drill pipe configured to be rotated to drill the borehole and a tube under axial tension and secured in the drill pipe, wherein the axial tension occurs at least with the drill pipe not under axial tension. The apparatus further includes a connector sleeve sealed to an end of the tube and configured to secure the tube under the axial tension to the drill pipe and to provide a sealing surface for a connector to seal to. The apparatus further includes a transmission line configured to communicate the signal. The transmission line is disposed in the tube and has a length greater than the length of the tube and extending past the connector sleeve.

Abstract: An apparatus for communicating a signal to or from a downhole tool includes a drill pipe configured to be rotated to drill a borehole, a tubular under axial tension and secured in the drill pipe, and a retention device secured to the tubular and configured to maintain the tubular under the axial tension. The retention device includes a portion extending from a body of the device in a direction that is non-inward-radial with respect to a longitudinal axis of the drill pipe. The apparatus further includes a transmission line disposed in the tubular and in an opening of the retention device and in communication with the downhole tool.