Abstract: Methods of exploiting a formation containing a reservoir of hydrocarbons utilize a gas-liquid drift-flux (DF) model for a multi-segmented wellbore (MSW). The DF model is provided for use in conjunction with a reservoir simulator. The DF model is configured to account for pipe inclinations of the MSW between ?90° and +90° including horizontal or near-horizontal wellbores in addition to vertical and slanted wellbores. The DF model is based on mixture velocity as opposed to superficial velocities, thereby permitting the DF model to be integrated with reservoir models that utilize mixture velocity. The DF model can also be continuous and differentiable over all primary variables.

Abstract: Before, during, and after a wellbore cementing operation temperature, pressure, and other conditions of a cement slurry are monitored downhole. The monitored conditions are compared to theoretical or calculated conditions to confirm the cementing operation is carried out in downhole conditions as planned. When differences between the monitored conditions and those used in planning the cementing operation exceed an acceptable range, adjustments are made to the cementing operation to account for the differences. The adjustments include changing a composition of the cement slurry to increase its design temperature, wellbore intervention if monitored pressure reveals a backflow of cement, and proceeding with another cementing stage if the monitored conditions indicate the cement slurry has cured into a set cement.

Abstract: In some embodiments, a downhole drilling system may include a pulse-generating circuit, a drill bit including a first pair of electrodes electrically coupled to the pulse-generating circuit to receive a first electrical pulse from the pulse-generating circuit and form a first electrical arc between the first pair of electrodes during a pulsed drilling operation. The system further includes a sensor to record responses to the first electrical pulse during the pulsed drilling operation and a sensor analysis system communicatively coupled to the sensor, where the sensor analysis system is configured to obtain a first measurement from the sensor representing the responses recorded by the sensor during the pulsed drilling operation. Additionally, the system may determine a first value of a dielectric constant associated with a portion of a formation in proximity to the drill bit, where the first value of the dielectric constant is based on the first measurement.

Abstract: Embodiments provide an expandable meshed component for guiding an untethered measurement device used in a subterranean well. The expandable meshed component includes an uphole radial portion, an intermediate radial portion, a downhole radial portion, an outer meshed wall, and an inner meshed wall. The expandable meshed component has a density less than a fluidic component occupying the space. A method for guiding an untethered measurement device used in a subterranean well includes deploying a compressed expandable meshed component tethered to the untethered measurement device, disconnecting the compressed expandable meshed component and the untethered measurement device, and releasing a sleeve surrounding the compressed expandable meshed component such that the expandable meshed component expands, ascends, and fits into an annulus.

Abstract: A damping device for use with a downhole tool having a tool axis and an expected operational temperature range, may comprise a device housing mechanically coupled to the tool and including a volume; and an inertia element movably supported in the receptacle and having a volume, a mass, and a non-zero moment of inertia about the tool axis. The inertia element may be supported within the receptacle such that the inertia element can move relative to the device housing and an interface between the device housing and the tool may include an area-altering feature. The device housing has a coefficient of thermal expansion that allows the interface to transmit a predetermined amount of torque and a predetermined amount heat across at expected operational temperatures. The interface may include a thermally conductive material in thermal contact with the device housing and the tool.

Abstract: A drilling dynamics data recorder is positioned within a slot in a downhole tool. The drilling dynamics data recorder may include a sensor package, the sensor package including one or more drilling dynamics sensors and a processor, the processor in data communication with the one or more drilling dynamics sensors. The drilling dynamics data recorder may also include a memory module, the memory module in data communication with the one or more drilling dynamics sensors and a communication port, the communication port in data communication with the memory module. The drilling dynamics data recorder may further include an electrical energy source, the electrical energy source in electrical communication with the memory module, the one or more drilling dynamics sensors, and the processor.

Abstract: Logging while drilling (LWD) mechanical calipers are disclosed. An example apparatus to characterize a bore includes a drill collar, a sliding sleeve that moves longitudinally relative to the drill collar, and a sliding block operatively coupled to the sliding sleeve and movable relative to the drill collar. The example apparatus also includes a caliper arm operatively coupled to the sliding block, where the caliper arm is to displace radially outward towards an inner diameter of the bore based on movement of the sliding block, and a caliper sliding sensor to measure a movement of the sliding block.

Abstract: A downhole sensor system may include at least two accelerometers having at least two axes of measurement. The at least two accelerometers may include a first accelerometer in a first position and a second accelerometer in a second position. A first axis of the second accelerometer may be substantially coaxial with a first axis of the first accelerometer and a second axis of the second accelerometer may be parallel to and offset from a second corresponding axis of the first accelerometer. The downhole sensor system may further include at least one processor, and at least one non-transitory computer-readable storage medium storing instructions thereon that when executed by the at least one processor may cause the processor to measure a first acceleration from the first accelerometer and measure a second acceleration from the second accelerometer.

Abstract: Embodiments of the disclosure provide a method for retrieving an untethered measurement device used in a subterranean well ascending from a wellbore into a Christmas tree valve. A swab valve of the Christmas tree valve is opened. An expandable meshed component is deployed into the Christmas tree valve through a swab conduit. The expandable meshed component transitions from a compressed configuration to an expanded configuration at a target height in the Christmas tree valve. A production wing valve of the Christmas tree valve is opened. The swab valve is closed. The untethered measurement device is retrieved from the Christmas tree valve through the swab conduit.

Abstract: A system for acid treating a section of a well includes a wireline or slickline extending from a surface of the well into the well and a bailer tool assembly attached to an end of the wireline or slickline. The bailer tool assembly includes a first piston positioned in a first piston housing at an axial end of at least one bailer, the first piston being slidable through the at least one bailer, at least one rotatable nozzle positioned at a lower end of the bailer tool assembly and fluidly connected to a fluid reservoir in the at least one bailer, and a depth indicator tool attached to an upper end of the bailer tool assembly.

Abstract: A downhole device comprising a novel apparatus and vibratory assemblage that initiates and maintains mechanical agitation within the horizontal section of a well bore by providing both low and high vibration, in multiple axes and planes, and through pulsing of high-pressure fluids within the confines of the apparatus and drilling pipe. Through the judicious and conservative use of fluids, the present invention provides both rotationally accelerated low and high vibration and high-intensity, directed and timed pressure to reduce the cumulative friction between the drill string and bottom hole assembly on a wellbore. Additionally, the present apparatus can be preprogrammed to respond to specific commands, in response to certain predetermined conditions, to stop and start functioning at various times throughout the drilling process.

Abstract: A guiding sleeve for aligning downhole tubulars includes a body having a first end portion, a second end portion and an intermediate portion extending therebetween. The first end portion is receptive of a terminal end of a first tubular and the second end portion includes a guiding feature that promotes axial alignment of the first tubular with a second tubular.

Abstract: A frac plug includes a body having an outer surface, a first pocket in the outer surface, and a second pocket in the outer surface. In addition, the frac plug includes a first sensor removably disposed in the first pocket. The first sensor is configured to measure and record a plurality of pressures. The frac plug also includes a second sensor removably disposed in the second pocket. The second sensor is configured to measure and record a plurality of pressures. Further, the frac plug includes a first cap releasably coupled to the body and closing the first pocket. Moreover, the frac plug includes a second cap releasably coupled to the body and closing the second pocket. The first cap includes a port and the second cap includes a port.

Abstract: A system and method to identify a dysfunction of a drill-string within a wellbore are provided. The system includes a sensor positioned proximate to a drill-string and proximate to a surface of the wellbore. The sensor is configured to sense a surface condition and generate measurement data. The system also includes a transmitter in communication with the sensor and configured to transmit the measurement data. The system also includes a receiver configured to receive the measurement data from the sensor. The system also includes a processor configured to calculate a downhole measurement based on the measurement data and analyze the downhole measurement to identify the dysfunction.

Abstract: A downhole, interventionless system and method of controlling fluid flow from a tubular string into isolated zones of a wellbore annulus utilizing fluidic devices having different flow restriction characteristics. In an embodiment, the system includes multiple fluidic devices positioned on a work string in fluidically isolated zones of a wellbore. Each fluidic device is configured with a different flow restriction characteristic that results in a different flow rate response when a working fluid having a particular initial fluidic property is introduced into the fluidic devices. By altering the initial fluidic property of the working fluid, the flow rate from the work string into the corresponding isolated zone may be adjusted and optimally controlled without the need for additional manipulation of the fluidic devices.

Abstract: A downhole system and method of performing an operational action with the downhole system. The downhole system includes a downhole string having a flow channel therethrough, a first turbine generator for generating electrical energy when a flow rate of a fluid through the flow channel is within a first flow rate range, and a second turbine generator for generating electrical energy when a flow rate of the fluid through the flow channel is within a second flow rate range. A first pulser at a downhole location in the downhole string transmits a pressure pulse communicative of data generated downhole using electrical energy generated by one of the first turbine generator and the second turbine generator. A sensor at a surface location receives the pressure pulse, and a control unit performs the operational action based on the data communicated by the pressure pulse.

Abstract: A removable real time clock battery (“RRTCB”) assembly is disclosed herein. The RRTCB assembly has an outer housing removably mounted in a port of a downhole tool. The outer housing is adapted to receive at least a portion of an inner housing. The inner housing has a cavity therein and is mounted in the port of the downhole tool. The inner housing is removably disposed within the outer housing. A real time clock battery is removably disposed in the cavity of the inner housing. The real time clock battery electrically connects to a clock disposed within the downhole tool. The RRTCB assembly can be readily removed from the downhole tool or bottomhole assembly (while at the earth's surface) without otherwise disassembling the downhole tool. The real time clock battery can then be removed and replaced or installed if not present.

Abstract: A method of managing bottom hole assembly vibrations while drilling a wellbore including obtaining data regarding drilling parameters related to one or more drilling operations, determining if the bottom hole assembly has vibration levels outside of the range of normal operation parameters, modifying the drilling mud formulation to alter at least one of its physical properties and rheological properties to keep or maintain the vibration levels of the bottom hole assembly within the range of normal operation parameters, and mitigating the vibrations.

Abstract: Certain aspects and features of the present disclosure relate to real-time management of excessive torque, drag, and vibration along a drill string. In some aspects, torque, drag, vibration or any combination of these may be monitored at locations along the drill string, and these forces may be mitigated by adjusting the drilling fluid composition in real time. In some aspects, the forces may be mitigated by making real-time operational changes during wellbore drilling instead of or in addition to drilling fluid treatments.

Abstract: An immersible ultrasonic transmitter consists of an end element of a first type, an end element of a second type and at least one transmitting member. The end element of the first type comprises a first cylindrical transmitter, a stack of piezoelectric elements, a second cylindrical transmitter and a coupling element with a threaded connection for coupling together the two cylindrical transmitters. The transmitting member contains a stack of piezoelectric elements, a cylindrical transmitter of a transmitting member, and an element with a threaded connection for coupling together the cylindrical transmitter of a transmitting member and the cylindrical transmitter of an adjacent transmitting member, or the second cylindrical transmitter of the end element of the first type.

Abstract: Systems and methods for detecting or monitoring treatment fluids in subterranean formations are provided. In certain embodiments, the methods comprise: providing an enhanced treatment fluid that comprises at least a base fluid and one or more contrast enhancement agents selected from the group consisting of: a magnetic material; a dispersive material; and any combination thereof, wherein the enhanced cementing fluid comprises one or more micro-electro-mechanical system (MEMS) sensors; and introducing the enhanced treatment fluid into at least a portion of a well bore penetrating a portion of a subterranean formation.

Abstract: A smart system for circulating LCM can implement a method. While a wellbore is being drilled in a geologic formation, drilling parameters identifying wellbore drilling conditions of a wellbore drilling system drilling the wellbore are received. The wellbore drilling system flows a wellbore drilling fluid including particulates of different size distributions. The particulates operate as LCM to reduce loss of the wellbore drilling fluid in the geologic formation. Size distributions of the particulates in the wellbore drilling fluid flowing through multiple different wellbore fluid flow pathways of the wellbore drilling system are received. The size distributions represent a concentration of the particulates in the wellbore drilling fluid. A release of certain particulates into the wellbore drilling fluid is controlled based, in part, on the received drilling parameters and the received size distributions of the particulates.

Abstract: A well annulus pressure control system includes a reservoir in fluid communication with a well annulus, a control valve disposed on a fluid coupling between the reservoir and well annulus, a sensor disposed in the well annulus that detects a well annulus pressure, a controller that is operatively coupled to the control valve and sensor. The controller detects the well annulus pressure of the fluid in the well annulus based on sensor data from the sensor, controls the control valve to release the fluid from the well annulus into the reservoir in response to determining that the detected well annulus pressure is higher than a normal operating range of pressure in the well annulus, and controls the control valve to refill the fluid from the reservoir back into the well annulus in response to determining that the detected well annulus pressure is lower than the normal operating range.

Abstract: The present disclosure describes methods and systems for analyzing drilling fluid rheology at a drilling site. One method includes obtaining, from a wellbore drilling system implementing a wellbore drilling operation at a wellbore drilling site, a sample of a drilling fluid being used in the wellbore drilling operation at the wellbore drilling site; flowing the sample through an elongated tubular member at a plurality of different flow rates, the elongated tubular member installed at the wellbore drilling site; measuring, at the wellbore drilling site and at each flow rate, a stress-strain response of the sample in response to each flow rate; generating a plurality of stress-strain responses for the sample at the corresponding plurality of different flow rates, the plurality of stress-strain responses including each stress-strain response of the sample measured at each flow rate; and returning the sample to the wellbore drilling operation.

Abstract: Methods, systems, and computer-readable medium to perform operations including determining, in real-time, values of drilling parameters of a drilling system drilling a wellbore. The operations further include calculating, based on the values of the drilling parameters, a cuttings concentration in an annulus of the wellbore (CCA). Further, the operations include calculating, based on the calculated CCA and a mud weight (MW) of a drilling fluid, an effective mud weight (MWeff) of the drilling fluid. Yet further, the operations include calculating, based on the effective mud weight, a slip velocity of the cuttings. In addition, the operations include calculating, based on the slip velocity, a transport ratio (TR) of the cuttings.

Abstract: A device for steering a drilling assembly including a sleeve configured to be disposed around a length of a drive shaft configured to be disposed in a borehole in an earth formation. The drive shaft is configured to be rotated. The sleeve is configured to be rotationally decoupled from the drive shaft. Two or more modules are configured to be removably connected to the sleeve. Each of the two or more modules at least partially encloses a biasing element configured to be actuated to control a direction of the drilling assembly. Each of the two or more modules at least partially encloses a communication device for wireless communication.

Abstract: Computing systems, computer-readable media, and methods may include determining at least one automated sequence to be performed during a portion of a drilling operation by a drilling system. The at least one automated sequence may include performing one or more actions to cause a response in the drilling system. The method may include performing, during the drilling operation, the at least one automated sequence. Further, the method may include measuring, during the performance of the at least one automated sequence, one or more responses in the drilling system. The one or more responses may be measured within a wellbore undergoing the drilling operations and at a surface of the wellbore. The method may include modifying a model of the drilling system based at least in part of the one or more responses that were measured during the performance of the at least one automated sequence.

Abstract: Apparatus and method for drilling a wellbore using non-synchronous oscillators. An apparatus for drilling a wellbore includes a tubing string and a bottom hole assembly coupled to the tubing string. The bottom hole assembly includes a first oscillator and a second oscillator. The first oscillator is configured to restrict fluid flow and induce pressure pulses in the tubing string at a first frequency. The second oscillator is configured to restrict fluid flow and induce pressure pulses in the tubing string at a second frequency. The first frequency is different from the second frequency.

Abstract: A method, system, and apparatus are provided for a configurable streaming operator to join or aggregate input data streams in a streaming application topology. The configurable operator may include a configuration data stream that allows for the selection of a varying number of input streams to join or aggregate. Introducing the configuration stream into a streaming operator allows the underlying operator to selectively use the remaining input streams based on the configuration stream as well as influencing the resulting output stream as defined by the configuration stream to provide flexibility in handling various configurations with a minimum and/or maximum of input streams.

Abstract: Ultrasonic transmitting elements in an electroacoustical transceiver transmit acoustic energy to an electroacoustical transponder, which includes ultrasonic receiving elements to convert the acoustic energy into electrical power for the purposes of powering one or more sensors that are electrically coupled to the electroacoustical transponder. The electroacoustical transponder transmits data collected by the sensor(s) back to the electroacoustical transceiver wirelessly, such as through impedance modulation or electromagnetic waves. A feedback control loop can be used to adjust system parameters so that the electroacoustical transponder operates at an impedance minimum. An implementation of the system can be used to collect data in a vehicle, such as the tire air pressure. Another implementation of the system can be used to collect data in remote locations, such as in pipes, enclosures, in wells, or in bodies of water.

Abstract: Aspects of the subject technology relate to a component module for a downhole tool. The component module can include a platform for components for use in the downhole tool, an enclosure covering the platform for components, wherein the enclosure is configured to fit within a pocket of the downhole tool, and an elastomer layer surrounding at least one portion of the enclosure and preventing the at least one portion of the enclosure from touching the pocket of the downhole tool.

Abstract: Disclosed are systems and methods for monitoring drilling fluids in real time. One method includes circulating a drilling fluid into and out of a borehole, generating a first output signal with a first optical computing device arranged near an outlet of the borehole, the first optical computing device having a first integrated computational element configured to optically interact with the drilling fluid, receiving the first output signal with a signal processor communicably coupled to the first optical computing device, determining the concentration of a gas present in the drilling fluid at the outlet of the borehole with the signal processor and generating a resulting output signal, conveying the resulting output signal to one or more peripheral devices, and adjusting one or more drilling or completion parameters in response to the concentration of the gas present in the drilling fluid.

Abstract: Systems and methods for determining the composition of a drilling fluid using electro-rheology may be provided. A method for drilling a wellbore may include: circulating a drilling fluid in a wellbore; extending the wellbore into one or more subterranean formations; measuring impedance of at least a portion of the drilling fluid over time as one or more particulate additives in the drilling fluid settle; determining one or more model elements of an equivalent circuit model for modeling frequency responses of the drilling fluid from the impedance; and determining sag behavior of the drilling fluid based, at least partially, on the one or more model elements.

Abstract: A pipe for cableless bidirectional data transmission and continuous circulation of a stabilizing fluid in a well for the extraction of formation fluids includes a hollow tubular body which couples with respective drill or completion pipes; a radial valve associated with the tubular body, the radial valve connectable to a pumping system outside the tubular body; an axial valve associated with the tubular body; a communication module associated with the tubular body that includes at least one metal plate selected from a transmitting metal plate, a receiving metal plate, and a transceiver metal plate; an electronic processing and control unit that processes signals to be transmitted by means of the at least one metal plate or signals received by means of the at least one metal plate; and one or more supply batteries for feeding the metal plates and the electronic processing and control unit.

Abstract: A bottom hole assembly is provided, having a housing having a housing lubricant channel; a motor having a rotor and a stator; a mandrel within the housing that rotates when drilling mud flows through the motor; a flex shaft within the housing that includes an internal fluid path for drilling mud to flow into the mandrel; a bushing between the housing and the mandrel having a spiral lubricant channel configured to pump lubricant while the mandrel rotates, such that lubricant in the housing lubricant channel returns to the spiral lubricant channel; first and second on-bottom thrust bearings; and a two stage rotor catch housing attached to the motor and having an internal shoulder, a rotor catch shaft, and a rotor catch nut attached to an upper end of the rotor catch shaft.

Abstract: The present invention relates to transmitting data using vector sensors and via the vector components of the acoustic field. The data can be received via vector sensors and/or scalar sensors and/or arrays of such sensors.

Abstract: A cable-type bridge plug setting and sealing tool, including a series of sequentially connected components provided in the following order: an upper connector, a driver, a control valve, a hydraulic actuator, and a piston adapter. When the control valve is in a first state, the driver sends, according to a first direction, a hydraulic fluid to the hydraulic actuator, thereby causing the hydraulic actuator to actuate a downward extension of the piston adapter. When the control valve is in a second state, the driver sends, according to a second direction, a hydraulic fluid to the hydraulic actuator, thereby causing the hydraulic actuator to actuate an upward retraction of the piston adapter. The cable-type bridge plug setting and sealing tool uses hydraulic control to achieve setting and sealing of a bridge plug, greatly reducing an operational risk coefficient and ensuring a degree of operational safety.

Abstract: A system and method for acquiring and processing single point viscosity measurements in well operations to predict flow curves, e.g., for mud flow, for monitoring and predicting viscosity of fluid flow in order to identify abnormal conditions for taking remedial action.

Abstract: A downhole system has a plurality of telemetry systems and a control system 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 and how the information is to be transmitted on the given telemetry system.

Abstract: Downhole casing temperature may be predicated at the drill string/casing interface as a function of side force on the casing due to drill string tension, the speed or rate of penetration of the drill string in the axial direction, the rate of rotation of the drill string, and a calibrated/assumed friction factor. Predicted down hole casing temperature may be used as a proxy to monitor casing integrity.

Abstract: A device for limiting the flow of drilling fluid through a section of drill string is described. The device includes a cylindrical tube with holes in its periphery. Flow enters the device through an upper end of the tube and a portion of the flow exits through the lower end of the tube. In addition, some of the flow is diverted through the peripheral holes. A valve piston is supported near the lower end of the tube by a spring of approximately constant force through its range of travel. The valve piston moves axially as the flow rate through the tube changes flow rate to ensure that a substantially constant amount of flow exits through the lower end, while the excess flow is diverted from the tube through the peripheral holes. A means of damping or stopping the axial movement of the valve piston is included in the device.

Abstract: An electromagnetic induction tool and method. The electromagnetic induction tool may comprise a tool body, a gap sub may separate different sections of the tool body and may be positioned to at least partially hinder the flow of an axial current and an azimuthal current on the tool body. A coil antenna may be disposed over the gap sub. A method of increasing an electromagnetic field may comprise providing an electromagnetic induction tool. The electromagnetic induction tool may comprise a tool body, a gap sub may separate different sections of the tool body and may be positioned to at least partially hinder flow of an axial current and an azimuthal current on the tool body. A coil antenna may be disposed over the gap sub. The method may further comprise placing the electromagnetic induction tool into a wellbore and operating the coil antenna.

Abstract: A method for determining a rate of penetration of a drill bit during an earth drilling operation may comprise first urging an element to extend out from a working face of the drill bit. As drilling progresses, this extended element may then be forced back into the drill bit by an internal surface of a borehole being formed. A rate at which the element retracts back into the working face may be measured to aid in estimating a rate of penetration of the drill bit into the earth.

Abstract: A method for reducing vibrations in a drill tubular coupled to a drill bit configured to drill a borehole in a formation includes: constructing a model of a system having the drill tubular, the model having a mass distribution, a stiffness, and/or a damping of the drill tubular; and calculating a plurality of modes using the model. The method also includes increasing an effective damping of the drill tubular for the plurality of modes by modifying at least one of the mass distribution, the stiffness, and the damping of the drill tubular using a predefined damping criterion, wherein the predefined damping criterion includes a ratio, the ratio having a deflection at the drill bit of at least one mode in the plurality and an eigenfrequency of the at least one mode in the plurality, wherein the deflection at the drill bit is raised to a power other than one.

Abstract: A downhole sensor includes a sensor housing with one or more of a pressure sensor or a temperature sensor. A cable segment having a conductor is coupled to the sensor housing. A spacer or retention element is coupled to or secured to at least a portion of the conductor at a location proximate an interface between the cable segment and the sensor housing. Downhole sensor arrays include such sensor housings. Methods relate to forming such sensor arrays.

Abstract: A method of recognizing input data includes determining a feature vector corresponding to an ensemble model from input data, based on the ensemble model, and recognizing the input data based on the feature vector. The ensemble model includes a first model and a second model having a structure that is the same as a structure of the first model.

Abstract: The present invention discloses an ultrasonic wellbore anti-collision monitoring system, comprising a downhole ultrasonic monitoring device and a ground control system, wherein the ultrasonic monitoring device includes a cylindrical body, at least three centralizers are fixed on the cylindrical body at an equal interval, the mounting groove 1 is cut into the cylindrical body surface between two adjacent centralizers, one electrically controlled expansion device is installed in the groove 1 and includes electric push rods placed horizontally and a ribbed plate perpendicular to the electric push rods, the bottom ends of the electric push rods are fixedly connected to the bottom surface of the mounting groove, the front ends of the electric push rods are connected with the ribbed plate, the mounting groove 2 is cut into the ribbed plate, and one ultrasonic transducer is installed in the groove 2.

Abstract: A system for drilling one or more boreholes in a face of a mine passage including markers attached to the mine passage. A drilling machine includes one or more drills for drilling the one or more boreholes, and a first sensor for sensing a position of the markers. Based on the sensed position of the at least two markers, a computer determines: (i) a survey vector generally parallel to the line; and (ii) a face plane generally orthogonal to the survey vector and coincident with a location where the survey vector intersects the face. A controller may be provided for automatically controlling the feeding of the drill(s) based on the location of the face plane and the back plane to form the boreholes in the face. A back plane may also be determined to ensure that all boreholes are drilled to a corresponding depth. Related methods are also disclosed.

Abstract: The invention relates to a system and method for estimating global rig state. The system comprises a model incorporating multiple variables related to rig state, at least one camera operably connected to at least one processor wherein said camera is capable of gathering visual data regarding at least one variable of rig state and said processor is capable of compiling rig state data, estimating global rig state, or both. The system further comprises multiple sensors for measuring variables related to global rig state wherein said sensors are operably connected to said processor. The method comprises sensing various aspects of the rig state, collecting visual data corresponding with said sensor data, compiling multiple sources of rig data, and estimating the overall rig state.

Abstract: Drill bits and methods relating thereto are disclosed. In an embodiment, the drill bit includes a body having a plurality of legs each having a lower section that has a leading surface and a trailing surface. A plurality of cone cutters are each rotatably mounted to the lower section of one of the legs, each having a cone axis, and including a first plurality of cutter elements arranged about the cone axis such that each is shear the formation when the body is rotated about the bit axis.