Abstract: A method for performing a subterranean operation that can include operations of engaging a tubular with a pipe handler, calculating, via a processor, an internal volume of the tubular, determining, via the processor, a number of pump strokes required to fill at least a percentage of the internal volume with fluid, pumping the fluid to the tubular by running a pump the number of pump strokes, and filling the internal volume of the tubular to at least the percentage of the internal volume with the fluid.

Abstract: A thixotropic composition having a cross-linkable polymer, cross-linking agent, initiator and a thixotropic agent. The thixotropic agent may be a clay or a saccharide polymer. The thixotropic composition may be introduced into a drill string via a batch or on-the-fly process to prevent loss of drilling fluid into the surrounding formation.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured tool body assembly having valving members (e.g., safety or kelly values) and valving members holding plugs, balls, or darts to be dropped. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members. A transmitter (or transceiver) provides an ability to generate a wireless signal that is received by receivers (or transceivers) on the tool body assembly. Each receiver (or transceiver) controls an electrical actuator that engages a valving member or the indicator. Wireless signals can be used to open or close a valve or to reset a “tripped” indicator.

Abstract: System and methods for optimizing wellbore tubular design are provided. Design parameters for a wellbore tubular component are determined based on different types of axial loads expected during a downhole operation. The design parameters include load conditions at load points along the tubular component. An equivalent axial load is calculated for each load point, based on the corresponding load conditions. Design limits for the different types of axial loads are determined based on associated design parameters. A counter-load pressure is determined for at least one load point selected for each type of axial load, based on the corresponding equivalent axial load for each load point and a corresponding design limit for each type of axial load. At least one of the design limits is adjusted for the different types of axial loads, based on the counter-load pressure of the selected load point for each type of axial load.

Abstract: A fluid pump test system. The fluid pump test system comprises a plurality of fluid tanks, each different fluid tank holding a different test fluid, a fluid plumbing, a plurality of valves coupling the fluid tanks to the fluid plumbing, and a compressed air source coupled to the fluid plumbing.

Abstract: A system for optimizing a tubular running operation (TRO) in which a running string is disposed in a wellbore includes sensors located at the wellsite, plus one or more processors, displays, and user-input devices, which may be at the wellsite or elsewhere. The sensors are configured to measure running string parameters including the running strings position within the well, the running and rotation rates, and loads acting at the top of the running string. Based on this information, the processor(s) perform torque-and-drag analysis (TDA) in the top-down direction to estimate downhole loads on user-selected running string components, accounting for measurement and modelling uncertainties. Based on the estimated loads, the processor(s) calculate one or more damage indicators, which are communicated to the user via the display(s), enabling the user to take corrective action to prevent or manage damage to the running string.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured tool body assembly having valving members (e.g., safety or kelly values) and valving members holding plugs, balls, or darts to be dropped. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members. A transmitter (or transceiver) provides an ability to generate a wireless signal that is received by receivers (or transceivers) on the tool body assembly. Each receiver (or transceiver) controls an electrical actuator that engages a valving member or the indicator. Wireless signals can be used to open or close a valve or to reset a “tripped” indicator.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured tool body assembly having valving members (e.g., safety or kelly values) and valving members holding plugs, balls, or darts to be dropped. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members. A transmitter (or transceiver) provides an ability to generate a wireless signal that is received by receivers (or transceivers) on the tool body assembly. Each receiver (or transceiver) controls an electrical actuator that engages a valving member or the indicator. Wireless signals can be used to open or close a valve or to reset a “tripped” indicator.

Abstract: A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities.

Abstract: A stress and strain sensing device capable of continuously sensing stress received from bedrock and strain of the bedrock over a long period of time is provided. A stress and strain sensing device has a pillar-shaped case to be buried and installed in bedrock, a pressure receiving member that has two pressure receiving surfaces for sensing stress received from the bedrock and strain of the bedrock, wherein the two pressure receiving surfaces are both arranged on a common axis orthogonal to an axial direction of the case such that the two pressure receiving surfaces are exposed to an outside through an outer peripheral wall of the case and wherein the two pressure receiving surfaces are not connected with the case mechanically, and a displacement sensor that senses the stress received from the bedrock and the strain of the bedrock based on a displacement amount between the two pressure receiving surfaces.

Abstract: A method of determining movement dynamics of a drillstring is provided that includes the steps of calculating or measuring a friction coefficient for the sliding contact between the drillstring and the sidewall of a borehole, the friction coefficient being a varying function of non-zero sliding velocities; and predicting movement dynamics of the drillstring using the measured friction coefficient.

Abstract: A method and apparatus for determining a stress field in a subterranean formation include deploying a stress measurement tool on a tubular string, opening at least three fractures in three different radial directions in the subterranean formation, and closing the at least three fractures. The at least three fractures are reopened while measuring stress and strain conditions. From the reopening, a tangential stress component for each of the at least three fractures is determined. From the tangential stress components and radial directions of the at least three fractures, the stress field of the subterranean formation is determined.

Abstract: A device is taught for measuring and wirelessly transmitting one or more parameters during wellbore operations. The device comprises a torque sub releasably connected to a top drive at a first end and having a second end such that the torque sub rotates with the rotating top drive, one or more sensors for measuring rotational, torque and torsion parameters, a wireless power source and a signal transmitter connected to the one or more sensors for wireless transmission of data collected by the one or more sensors to a computer. Systems and methods are also provided for connecting threaded tubulars for use in a wellbore.

Abstract: Systems and methods for determining the bending moment and shear force of tubing and casing when the tubing buckles and contacts the casing.

Abstract: A device for measuring the torque or force exerted by a drilling machine during a rotation, driving or lifting of a tool. The measuring device includes an engaging device with a drilling battery or with a shaft of at least a drilling equipment or rotary of the machine the engaging device is susceptible of symmetrically or axial-symmetrically locking the drilling battery or the shaft preventing the rotation and/or the axial displacement in a position in correspondence to the tool. The engaging device is associated with at least a transducer for the detection of at least a maximum torque or of at least a maximum force exerted by the machine; and the measuring device is fixedly constrained to the drilling battery or to the shaft.

Abstract: An apparatus for estimating at least one of a dynamic motion of a portion of interest of a drill string and a static parameter associated with the portion of interest, the apparatus having: a plurality of sensors operatively associated with the drill string at at least one location other than the portion of interest; and a processing system coupled to the plurality of sensors, the processing system configured to estimate at least one of the dynamic motion and the static parameter using a measurement from the plurality of sensors as input.

Abstract: A sensing cable, including an outer cladding; and at least one sensing bundle contained within the cladding, each sensing bundle having a sensing fiber wrapped strain-transmissively by at least one strand. A method of sensing strain is also included.

Abstract: Disclosed herein is a method of locating and quantifying friction between a drillstring and a wellbore. The method includes, positioning a plurality of sensors within a wellbore, communicatively coupling the plurality of sensors, monitoring signals from the plurality of sensors, logging the sensed signals versus time versus depth of each of the plurality of sensors, locating at least one friction zone along the drillstring within the wellbore based on the logging and quantifying friction in the at least one friction zone based on the logging.

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 sensor for measuring force, the sensor including: a light source; and a mixing medium in optical communication with the light source and exposed to the force; wherein four wave mixing of light interacting with the mixing medium provides a signal that indicates the force.

Abstract: An apparatus and method for determining forces on a downhole drilling tool is provided. The downhole tool is provided with a drill collar operatively connectable to the drilling tool, and a sensor mounted about the drill collar. The sensor is adapted to measure deformation of the drill collar whereby forces on the drilling tool are determined. The sensor may be part of a force measurement system, a strain gauge system or a drilling jar system. The drill collar is adapted to magnify and/or isolate the deformation applied to the drill string.

Abstract: An apparatus and method for determining forces on a downhole drilling tool is provided. The downhole tool is provided with a drill collar operatively connectable to the drilling tool, and a sensor mounted about the drill collar. The sensor is adapted to measure deformation of the drill collar whereby forces on the drilling tool are determined. The sensor may be part of a force measurement system, a strain gauge system or a drilling jar system. The drill collar is adapted to magnify and/or isolate the deformation applied to the drill string.

Abstract: The present invention relates to methods for determining the existence and location of parasitic stress-inducing forces on a substantially cylindrical rod portion 1 defined along a first axis 2 and when this rod is made of a magnetostrictive material. The method according to the invention is essentially characterized in that it consists in magnetizing the wall of the rod portion in a pseudo-helix 10 centred on the first axis 2, in applying a forced stress between the two ends 3, 4 of the rod portion 1, in measuring, along the rod portion, the magnitude of the magnetic field created by the rod portion 1 after it has been subjected to the forced stress, these measurements being taken in a direction substantially parallel to the first axis 2, and from these measurements, in deducing the existence and location of the parasitic stress-inducing forces on the rod portion 1. The invention also relates to a device for implementing this method.

Abstract: An apparatus and method for determining forces on a downhole drilling tool is provided. The downhole tool is provided with a drill collar operatively connectable to the drilling tool, and a sensor mounted about the drill collar. The sensor is adapted to measure deformation of the drill collar whereby forces on the drilling tool are determined. The sensor may be part of a force measurement system, a strain gauge system or a drilling jar system. The drill collar is adapted to magnify and/or isolate the deformation applied to the drill string.

Abstract: The present invention provides methods and apparatus for measuring subterranean strain. The methods and apparatus use fluid expansion principles to compensate for temperature variations and increase the accuracy of the strain measurements. The methods and apparatus contemplate the use of multiple fluid chambers according to some embodiments in order to remove temperature dependence from stress or strain measurements.

Abstract: The invention includes a wireless communication circuit and a method of communicating with wireless signals that feature a tank circuit having an inductor connected in parallel with a capacitor circuit. The capacitor circuit includes a pair of capacitors coupled in series. Each of the capacitors is connected in common to ground and has a capacitive value associated. A feedback network is connected to selectively bias the tank circuit to produce a signal having an amplitude. The amplitude of the signal is a function of a ratio of the capacitive values associated with the capacitor circuit. The frequency of the signal is defined by the inductor and the capacitor circuit. The tank circuit is multifunctional in that it may be biased to function as a transmitter and a receiver.

Abstract: A system and method for acquiring seismic data are disclosed. The system comprises a controller for causing the generation of a seismic signal, where the controller has a first clock used for time-stamping a record of the generated seismic signal. A seismic receiver is deployed in a wellbore so as to detect the generated seismic signal. An atomic clock is disposed in or with the seismic receiver for time-stamping a record of the detected seismic signal. The atomic clock is synchronized with the first clock prior to being placed downhole.

Abstract: A survey tool for use in a wellbore includes a downhole portion having an axis. The downhole portion is adapted to move within the wellbore with the axis generally parallel to the wellbore. The survey tool further includes a first acceleration sensor mounted at a first position within the downhole portion. The first acceleration sensor is adapted to generate a first signal indicative of an acceleration of the first acceleration sensor along the axis. The survey tool further includes a second acceleration sensor mounted at a second position within the downhole portion. The second position is spaced from the first position by a non-zero distance along the axis. The second acceleration sensor is adapted to generate a second signal indicative of an acceleration of the second acceleration sensor along the axis.

Abstract: A system and method for acquiring seismic data are disclosed. The system comprises a controller for causing the generation of a seismic signal, where the controller has a first clock used for time-stamping a record of the generated seismic signal. A seismic receiver is deployed in a wellbore so as to detect the generated seismic signal. An atomic clock is disposed in or with the seismic receiver for time-stamping a record of the detected seismic signal. The atomic clock is synchronized with the first clock prior to being placed downhole.

Abstract: A method and apparatus for detecting torsional vibration, or stick-slip, in a drill string while drilling is described. The method comprises sampling a downhole pressure sensor and using embedded filter schemes and algorithms to determine, based on the pressure samples, whether torsional vibration is occurring in the drill string. The method may also include sending a warning signal to the surface of the well. The apparatus comprises a downhole assembly having a downhole receiver and a master controller. The downhole receiver comprises a pressure sensor, filter schemes, and algorithms for detecting torsional vibration. The downhole assembly may also include a downhole transmitter for sending a warning signal to the surface of the well.

Abstract: The invention is directed toward a subsurface gravity measurement device and a method for calibrating the same that includes a tilt meter and a gravity sensor. The method includes associating tilt information produced by the gravity sensor as a function of a relationship between tilt information produced by the tilt meter and a correction parameter. The tilt meter produces tilt data, and the gravity meter produces gravity data, corresponding to the tilt data. The tilt data and gravity data is fitted to a polynomial equation that has a plurality of initial coefficients associated therewith. The initial coefficients includes information concerning the correction parameter. The correction parameter is derived as a function of the initial coefficients.

Abstract: The invention comprises wireless low frequency downhole detection, monitoring and communication capable of operation at greater depths than prior methods and capable of detection with standard equipment and/or standard data, thereby improving system cost, utility, reliability and maintainability.

Abstract: A torque swivel apparatus. The apparatus includes an upper body assembly secured to the lower end of a locking swivel of the type used in wireline operations. The upper body would engage into a lower body, the lower body secured to the drill string at the rotary table. The upper body would provide a pair of milled out wedge portions for accommodating a pair of wedge members in the lower body to engage therein during coupling. The apparatus further includes a plurality of cylinders positioned into the upper body with a piston member secured within each cylinder, so that each of the four faces of the wedge portions of the upper body accommodates a pair of pistons in its wall. The outer face of each of the pistons would make contact with each of the four faces of the wedge members of the lower body when coupling has occurred. The inner face of each of the pistons would mate with a line having fluid, which when acted upon would register force against the piston.

Abstract: An apparatus for measuring the weight and torque on a drill bit operating down hole in a well. The apparatus comprises at least three pockets circumferentially spaced equidistantly around the drill collar of the drill string to which the drill bit is attached. Eight strain gages are equidistantly circumferentially spaced around each of the pockets so as to form first and second sets of strain gages. The strain gages in the first set are connected into one Wheatstone bridge while the gages in the second set are connected in a second bridge. Each of the strain gages that are oriented similarly within each of the pockets are connected in series within a single leg of a bridge so that the output voltage of the bridge is unaffected by bending in the drill string. The output of first bridge is used to determine the weight on the drill bit while the output of the second bridge is used to determine the torque on the drill bit.

Abstract: A device to monitor and quantify the tension and compression forces acting on a well logging instrument string during deployment. The device eliminates the undesirable effects of downhole hydrostatic pressure on the sensors, and eliminates the need for a costly, complex, and high maintenance hydraulic pressure equalizing system in the force gage assembly. The device provides improved measurement accuracy, provides enhanced reliability and longer life of the sensors, and allows lower cost of manufacture and maintenance.