Abstract: A device for measuring strain on the exterior of a pipe includes a body comprising a top portion and a bottom portion; one or more elastically deformable members coupled between the top portion and the bottom portion, wherein each of the one or more elastically deformable members have an outer contact surface and an inner non-contact surface. One or more sensors are disposed on the inner non-contact surface of one or more of the elastically deformable members. The sensors, during use, provide data that can be used to determine changes in strain on the exterior of the pipe. In another embodiment, one or more sensors are embedded in, or attached to, a casing disposed in a wellbore. In an embodiment, a method includes pressurizing or depressurizing the wellbore with a fluid and measuring the strain induced in the casing (or in an open wellbore) in response to this change in wellbore pressure.

Abstract: A system and method of drilling a wellbore to a target may include measuring attitudes at two adjacent survey stations along a wellbore using a downhole surveying tool. An actual change in wellbore position over a survey leg linking the two survey stations may be determined. Corrections may be applied to the measured attitude at one or both of the survey stations such that an estimated well path joining the survey stations indicates the determined actual change in wellbore position between the two survey stations.

Abstract: Systems, apparatus and methods are described for purposes of initiating a response to detection of an adverse operational condition involving a system including a drill rig and an inground tool. The response can be based on an uphole sensed parameter in combination with a downhole sensed parameter. The adverse operational condition can involve cross-bore detection, frac-out detection, excessive downhole pressure, a plugged jet indication and drill string key-holing detection. A communication system includes an inground communication link that allows bidirectional communication between a walkover detector and the drill rig via the inground tool. Monitoring of inground tool depth and/or lateral movement can be performed using techniques that approach integrated values. Bit force based auto-carving is described in the context of an automated procedure.

Abstract: Apparatus and methods can be conducted in a multi-pipe structure to determine eccentricity of one or more pipes of the multi-pipe structure. A tool having a center axis as a symmetry axis of the tool can be used in which receivers are arranged as a number of pairs of receivers around the center axis of the tool. Each receiver of a pair can be disposed opposite the other receiver of the pair with respect to the center axis such that each pair is symmetrical with respect to the center axis of the tool. Eccentricity of one or more pipes of the multi-pipe structure can be determined based on the received responses at the receivers of the pairs.

Abstract: Provided in some embodiments is a well torpedo system that includes a torpedo adapted to be advanced in a wellbore of a subterranean well. The torpedo including an integrated spool adapted to hold a fiber-optic (FO) umbilical including a FO line adapted to couple to a surface component, and an engine adapted to combust solid propellant to generate thrust to propel advancement of the torpedo in the wellbore.

Abstract: A well casing is cemented in a well bore in a subterranean formation by pumping cement slurry down into the well casing so that the cement slurry flows up into an annulus surrounding the well casing. While pumping the cement slurry, the position of the top of the cement slurry in the annulus is sensed, and the rise of the sensed position of the top of the cement slurry in the annulus is recorded as a function of time. The recording is analyzed to evaluate the cement job. For example, the analysis may indicate a problem addressed by adjusting a cement plan for a future cement job, and the analysis may indicate a need to repair a location of the set cement by perforating the well casing at the location to be repaired, and pumping cement slurry down the well casing to fill the location to be repaired.

Abstract: A system and method for providing information regarding the tortuosity of a wellbore path is provided. The method includes receiving data from a plurality of survey stations of a wellbore survey. The method further includes determining a plurality of tortuosity parameter values for the wellbore path within a corresponding plurality of analysis windows, wherein each analysis window has at least one tortuosity parameter value.

Abstract: Downhole drilling vibration analysis uses an angular rate sensor on a drilling assembly. During drilling operations, the sensor measures the angular rate of the drilling assembly. Processing circuitry is operatively coupled to the angular rate sensor and is configured to determine whether torsional type vibrations are occurring during drilling based on the angular rate data. Drilling operations can then be modified to overcome or mitigate the torsional type vibrations.

Abstract: A resistivity-measuring sensor disposable within a drillstring includes a sensor body having a longitudinal axis, wherein the sensor body is separable from and disposable in the drillstring at a radially offset distance from the longitudinal axis of the drillstring. The sensor further includes a transmitting antenna disposed along a length of the sensor body, a receiving antenna disposed along a length of the sensor body, and an electronics section contained within the sensor body for generating and receiving signals to and from the transmitting and receiving antennas.

Abstract: The invention relates to a system and a method for determining flow patterns of fluid in a production well. Especially, the invention relates to a method of determining flow patterns between and into oil production wells drilled in the Earth when flow is improved by water flooding. The system comprises a canister (1) said canister being located in said formation at a subterranean location within or proximate the wellbore, the canister being provided with an exit opening (5), a traceable component (4) being placed in the canister and able to pass through the exit opening and a release mechanism capable of releasing the traceable component when triggered by a triggering mechanism such that the traceable component enters the fluid flowing through the well through the exit opening and is present in the fluid flow in the wellbore.

Abstract: A fiber optic sensor is provided. The fiber optic sensor includes: a fixed portion configured to be secured to a body of interest; a moveable portion; a spring member positioned at least partially between the fixed portion and the moveable portion; an optical fiber wound in contact with the fixed portion and the moveable portion such that the optical fiber spans at least a portion of the spring; and an elastomeric material provided in contact with at least one of the fixed portion, the moveable portion, the spring member, the body of interest, and the optical fiber.

Abstract: A one trip system for perforating and fracking multiple intervals uses a releasable barrier. The barrier can be an inflatable. A pressure booster system is associated with the BHA so that the existing hydrostatic pressure is boosted when the gun or portions thereof are fired. After firing in one interval, the BHA is raised and the barrier is redeployed and the pattern repeats. Instruments allow sensing the conditions in the interval for optimal placement of the gun therein and for monitoring flow, pressure and formation conditions during the fracturing. Circulation between gun firings cleans up the hole. If run in on wireline a water saving tool can be associated with the BHA to rapidly position it where desired. A multitude of perforation charges mounted in the BHA can be selectively fired by selected corresponding detonator based on a predetermined sequence or surface telemetry command.

Abstract: The present invention relates to a downhole tool extending in a longitudinal direction, comprising a tool housing; an arm assembly pivotally mounted about a pivot point fixed in relation to the tool housing and movable between a retracted position and a projecting position in relation to the tool housing; an arm activation assembly for moving the arm assembly between the retracted position and the projecting position, the arm activation assembly being arranged inside the tool housing and having a first end face and a second end face adapted for being connected with the end faces of other arm activation assemblies; wherein the arm activation assembly comprises: a piston housing having a piston chamber extending in the longitudinal direction of the downhole tool and comprising: a first piston housing part, a second piston housing part removably connected to the first piston housing part, a piston member arranged inside the piston housing and connected with the arm assembly, the piston member being movable in th

Abstract: An ultrasonic flow meter is equipped with a housing through which a liquid flows, and a pair of detection units disposed on opposite ends of the housing and including acoustic wave transmitting and receiving units capable of transmitting and receiving acoustic wave signals. Paired connecting plugs are connected respectively to both ends of the housing. In addition, a supply passage of one of the connecting plugs, a conduit of the housing, and a discharge passage of another of the connecting plugs are disposed on a straight line. A liquid supplied to the supply passage flows through a passage of the conduit and to the discharge passage. Consequently, a flow rate of the liquid is measured based on the propagation time of the acoustic wave signals, which are transmitted and received by the acoustic wave transmitting and receiving units.

Abstract: A sensing subassembly for use with a downhole tool comprises a housing, a cavity disposed within the housing, an electronic board disposed within the cavity, a stiffening member engaging the electronic board and configured to limit flexing of the electronic board, and a spring member configured to provide an isolation mount for the electronic board within the cavity.

Abstract: A method for drill pipe tallying includes detecting that a drill bit (14) has tripped in through a rig floor and monitoring movement of a drawworks (6) that supports the drill bit and a length of drill pipe. If a tag interrogating device does not detect a wireless tag (26) associated with a set of slips, the method includes counting the movement of the drawworks toward a drill pipe tally. If a tag interrogating device detects a wireless tag associated with a set of slips, the method includes not counting the movement of the drawworks toward the drill pipe tally. The tag interrogating device is positioned at a fixed location relative to the rig floor.

Abstract: A communication system can include a transmitter which transmits a signal, and at least one sensing device which receives the signal, the sensing device including a line contained in an enclosure, and the signal being detected by the line through a material of the enclosure. A sensing system can include at least one sensor which senses a parameter, at least one sensing device which receives an indication of the parameter, the sensing device including a line contained in an enclosure, and a transmitter which transmits the indication of the parameter to the line through a material of the enclosure. Another sensing system can include an object which displaces in a subterranean well. At least one sensing device can receive a signal from the object. The sensing device can include a line contained in an enclosure, and the signal can be detected by the line through a material of the enclosure.

Abstract: A method for obtaining seismic information about a subsurface formation using at least one fiber optic cable having its proximal end coupled to a light source and a photodetector comprises: transmitting into the cable at least one light pulse; receiving at the photodetector a first and second light signals indicative of the physical status of at least one first cable section and at least one second cable section, respectively, wherein the first and second sections are selected so as to provide first and second information items, respectively; optionally, further processing at least one of the first and second information items so as to produce derivative information; and outputting at least one of the first, second, and derivative information items to a display; wherein the second item differs from the first item in at least one aspect selected from the group consisting of: resolution, area, and location.

Abstract: A system and method for use in a downhole tool having distance measurement, feature detection, and primary measurement devices positioned therein are provided. In one example, the method includes recording a first plurality of features and corresponding positions in a first log using the feature detection device and the distance measurement device, respectively. A first feature of the first plurality of features is selected and the position corresponding to the first feature is identified. The feature detection device is aligned relative to the first feature based on the identified position. A first primary measurement is taken using the primary measurement device while the feature detection device is aligned relative to the first feature. The steps of recording, selecting, moving, and taking are repeated to obtain a second primary measurement while the feature detection device is aligned relative to a second feature of a second plurality of features.

Abstract: A capsule comprising two non-directly contacting halves enables otherwise coupling loads between experiment and gauging to be re-routed through the outer-most portable body (e.g. a logging sonde housing) having substantial inertia, thus serving to attenuate the parasitic loads. For co-located leveled experiment and gauging, a pair of concentric bearings (shaft in shaft) is utilized. Independent bearing sets and shock/vibration isolation support each capsule half within the outer sonde housing. A first half of the capsule supports the experiment, which the second half supports the gauging apparatus.

Abstract: Apparatus is provided for use in power generation, including a fluid-flow-driven power generator for use in a fluid-containing pipe such as a drill pipe as used in oil and gas exploration and extraction. Parts of the generator are removable from the pipe—for example while a drill pipe is downhole within a drilling well—to leave a clear through bore for survey and fishing operations and to enable replacement of the removed parts. The flow-driven generator comprises an impeller connected to a magnet assembly to rotate the magnet assembly when fluid flows past the impeller. This causes relative movement between the magnet assembly and an adjacent electrical coil assembly, the relative movement and magnetic coupling generating an electrical current in the coil assembly. This generated electrical current is used to power electrical devices within the pipe.

Abstract: The present disclosure introduces pressure-equalized packaging for electronic sensors utilized in conjunction with downhole tools and/or other extreme environments. Such sensors may be operable to detect, sense, and/or measure a parameter, such as may be associated with the downhole tool, or pressurized fluid in which the downhole tool is at least partially submerged, or a subterranean formation adjacent the downhole tool. A housing couples the sensor to a component of the downhole tool. The housing includes an equalizer operable to substantially equalize a first pressure internal to the housing with a second pressure external to the housing.

Abstract: A method and apparatus are provided for detecting a structural stability of an object area. The method and apparatus include disposing a plurality of electrodes in the object area along a depth direction of the object area, surrounding the electrodes with a filling material; measuring a micro potential difference via the electrodes, generating a micro potential difference when the filling material is deformed by a force according to a change of the object area; and determining the structural stability of the object area based upon the measured micro potential difference.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to draw a formation fluid sample into a sampling port included in a down hole tool, to vaporize some part of the fluid sample to substantially fill an injection port with a gas phase, to differentiate gas components in the gas phase to provide differentiated gas components along a concentration gradient, to detect the differentiated gas components, and to determine a fingerprint of the differentiated gas components. Other apparatus, systems, and methods are disclosed.

Abstract: A method of well testing to determine properties of oil and gas wells 8 comprises: applying oscillations to the flow rate and/or pressure at multiple wells 8 wherein the oscillations applied at different wells of the multiple wells are at different test frequencies; receiving measurements of flow rate in flows downstream of a production header that combines the flows from the multiple wells 8, and/or receiving measurements of pressure and/or temperature from individual wells 8; carrying out a frequency analysis of the pressure, flow rate and/or temperature measurements to determine pressure, flow rate and/or temperature variations induced by the applied oscillations; and determining properties of the different wells 8 of the multiple wells 8 based on the results of the frequency analysis at the test frequencies for the wells 8.

Abstract: Methods and apparatus for acquiring acceleration waveform measurements while deploying a tool along a borehole. A conveyance and a sensor section are configured to deploy the sensor section in the borehole. At least one multi-axis receiver is configured to detect acceleration waveform signals while the sensor section is being deployed in the borehole.

Abstract: The present disclosure provides systems, tools, and methods for enhancing a measurement of a property of a solid body or fluid. The systems, tools, and methods may involve an electromagnetic measurement tool that includes a transmitter configured to transmit electromagnetic energy, a receiver configured to receive the electromagnetic energy, and a metamaterial element comprising a negative refractive index. The metamaterial element may focus the electromagnetic energy. The electromagnetic tool may be placed adjacent the solid body or fluid, electromagnetic energy may be transmitted via the transmitter, and the electromagnetic energy may be received with the receiver to measure a property of the solid body or fluid.

Abstract: A borehole instrument includes an image sensor for capturing images of an inside wall of a borehole. A borehole profile may also be measured by, for example, a laser. The same image sensor may be used for image capture and profile measurement. Different image sensors may be used for image capture and profile measurement. Image capture and profile measurement may be performed with reference to the same depth measurement, so that images and profiles are depth-aligned at capture. Orientation of the instrument within the borehole may also be measured to compensate for rotation of the instrument. A communications subsystem can transmit image data, profile data, and orientation data to a computer located outside the borehole for storage and analysis.

Abstract: A method of monitoring downhole assets includes tracking a location of a downhole asset relative to a first environment. The configuration information for the downhole asset is acquired, where the configuration information comprises a measurement of one or more forces applied to the downhole asset during assembly of the downhole asset in the first environment. A service life of the downhole asset is determined from the configuration information. One or more parameters related to usage of the downhole environment in a second environment are measured. A remainder of the service life of the downhole asset is determined by reducing the service life by an amount proportional to usage of the downhole asset as indicated by the measurement related to usage of the downhole asset. The remaining service life may be used to automatically initiate an order for new parts. A system of monitoring downhole assets is also disclosed.

Abstract: A sensing system comprises at least one gauge disposed in a wellbore, a sensing link coupled to the at least one gauge, and a debris barrier coupled to the sensing link. The debris barrier comprises a housing coupled to the sensing link, and a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link.

Abstract: An exemplary embodiment of the liner top test tool comprises a mandrel that is coupled to a sealing assembly, which contains at least one radially extendable sealing element, and a test tool support which is axially displaceable in relation to the mandrel. The test tool support contains at least one shearable element preventing axial movement of the test tool support in relation to the mandrel. The mandrel has at least one axial groove that can be coupled to the test tool support in order to limit the amount of axial movement between the two components. Once the tool is in place on a liner top, the shearing of the shearable element will activate the tool by allowing the mandrel to be displaced axially in relation to the test tool support thereby applying axial pressure on the sealing element causing it to radially extend and seal the bore of the liner.

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 method and system to perform distributed downhole acoustic sensing in a borehole are described. The system includes an optical fiber comprising at least one reflector, and a tunable laser configured to perform a transmission of a range of wavelengths through the optical fiber. The system also includes a receiver configured to receive an interferometer signal resulting from the transmission, and a processor configured to determine a component of the interferometer signal.

Abstract: Downhole gauge (1) assembly comprising a gauge housing (3) with a receiving aperture (32) having a sealing means (30) with an inner sealing surface (8). A gauge (4) is arranged in or in association to the gauge housing (3), a metal cable (7) with an inner bore is in communication with the interior of the housing (3). The cable runs from a downhole location to the top of a subsurface well. An electrical or optical conductor (9a, 9b) runs through the bore of the metal cable. The conductor (9a, 9b) is connected to the gauge (4) through a connector (5). The electrical or optical connector (5) is arranged within the gauge housing (3) and has been passed through said receiving aperture (32) of the gauge housing (3). The inner sealing surface (8) seals on the outer surface of the metal cable (7).

Abstract: A sensing system configured for use in a borehole. The sensing system includes a body portion and a clamp arm engaged with the body portion. The clamp arm is configured to move between a retracted position and an extended position. The sensing system also includes an energy storage element engaged with the body portion. The energy storage element provides energy to move the clamp arm from the retracted position to the extended position. A method of using the sensing system is also provided.

Abstract: An apparatus and method to monitor parameters outside the wellbore casing of a well includes a Wireless Sensor Unit located outside a section of a non-magnetic casing of the well. The Wireless Sensor Unit includes a sensor device to measure parameters of the surroundings. The apparatus further includes an internal Sensor Energizer Unit inside the wellbore casing used for power and communication with the Wireless Sensor Unit. The Sensor Energizer Unit and the Wireless Sensor Unit are arranged to be at the same elevation, and they communicate data using electromagnetic modulation techniques.

Abstract: An apparatus and method to provide monitoring of pressure outside the wellbore casing of a well in which a Wireless Sensor Unit is placed externally of a section of non-magnetic casing. An internal Sensor Energizer Unit is placed inside the wellbore casing. The Wireless Sensor Unit includes one or more sensors to measure the pressure and/or temperature of the surroundings. The Wireless Sensor Unit and the Sensor Energizer Unit communicate using electromagnetic modulation techniques, and the Wireless Sensor Unit may be powered by means of power harvesting from the Sensor Energizer Unit.

Abstract: Systems and methods for distributed downhole sensing in which a polymeric sensor system is coupled to one or more pieces of downhole equipment. The polymeric sensor system has multiple electric or nano sensors embedded in a polymeric material such as a tape that can be applied to the downhole equipment to sense parameters at multiple, physically distributed locations. A monitoring unit at the surface of the well may receive data from the embedded sensors. A control unit at the surface of the well may communicate control information through the polymeric sensor system to electrically controlled equipment downhole, eliminating the need for a control line that is separate from the polymeric sensor system.

Abstract: A communication system can include a transmitter which transmits a signal, and at least one sensing device which receives the signal, the sensing device including a line contained in an enclosure, and the signal being detected by the line through a material of the enclosure. A sensing system can include at least one sensor which senses a parameter, at least one sensing device which receives an indication of the parameter, the sensing device including a line contained in an enclosure, and a transmitter which transmits the indication of the parameter to the line through a material of the enclosure. Another sensing system can include an object which displaces in a subterranean well. At least one sensing device can receive a signal from the object. The sensing device can include a line contained in an enclosure, and the signal can be detected by the line through a material of the enclosure.

Abstract: A method and system for monitoring the integrity of a water aquifer is provided. The method and system generally monitors an aquifer for subsurface fractures, fluid intrusion, or water contamination. In one embodiment, the method and system may be utilized before, during, and after contaminating operations to monitor a water aquifer and generate reports detailing the effect of the contaminating operations on the water aquifer. The reports, and associated raw data, may be used as legal documents. For example, in one embodiment, an independent company is responsible for monitoring the aquifer and generating reports, which are then submitted to all interested parties, including the state for regulatory purposes.

Abstract: Apparatus and systems, as well as methods, may operate to draw a formation fluid sample into a sampling port included in a down hole tool or tool body, to vaporize some part of the fluid sample to substantially fill an injection port with a gas phase, to differentiate gas components in the gas phase to provide differentiated gas components along a concentration gradient in a receiving section, to detect the differentiated gas components with a detector, and to determine a fingerprint of the differentiated gas components. A reaction section and a vacuum section may be used for waste consumption and/or absorption.

Abstract: A downhole sensor to detect characteristics in a borehole comprises at least one sensing unit to sense a characteristic in the borehole and a metallic layer covering at least a portion of the sensing unit exposed to an interior of the borehole.

Abstract: A down hole surveying tool (10) is for directional surveying of boreholes. The tool (10) includes a body (11) which accommodates a composite sensor device (17). The sensor device (17) is supported for rotation about an indexing axis (4) in a rotary mount (31) which provides an indexing platform (33). The sensor device (17) can be indexed about the indexing axis between two indexing positions which are 180 degrees apart. An indexing mechanism (70) is provided for selectively indexing the sensor device (17) about the indexing axis (4). The sensor device (17) includes a two-axis gyroscope (13) and a two-axis accelerometer (15) connected together and rotatable in unison. The indexing axis (4) is perpendicular to the two sensitive axes of the gyroscope (13) and the two sensitive axes of the accelerometer (15). The gyroscope (13) and accelerometer (15) are rigidly fixed with respect to each other to provide a sensor package which constitutes the composite sensor device (17).

Abstract: Systems and methods for downhole measurement and communications are disclosed. The system includes a communications medium, at least partially disposed in a drillpipe, a processor coupled to the communications medium, at least two sensor modules coupled to the communications medium, where at least one of the sensor modules is along a drillpipe, and at least one communications coupler to couple at least one sensor module to the communications medium.

Abstract: An apparatus for the testing of downhole an injection assembly prior to installation of the injection assembly in the completion string is disclosed. The apparatus is comprised an injection tubing, an injection sub, an injection valve, an injection sub test block, a pressure foot, a pressure foot test block, and means for introducing pressure at a desired level. The injection sub test block, pressure foot, pressure foot test block are interchangeably engageable with the injection sub for testing in a sequence to allow the pre-testing of the connections of components of the injection assembly at the surface of the well.

Abstract: A coiled member measuring device includes a main frame fixedly anchored in relation to the outer casing or the coiled member handling device of a well and an inner housing supported by the main frame for unrestricted lateral movement in at least two different directions transverse to one another and in a common plane oriented perpendicularly to an axial direction of the outer casing. Followers in the inner housing surround an axial passage receiving a coiled member such as coiled tubing or continuous rod therethrough. Two adjacent followers are supported in a V-shaped pattern for sliding movement diametrically opposite a third remaining follower. Sensors associated with the followers permit determination of overall circumference and length of the coiled member.

Abstract: A tool for testing a tubular has a shaft with a fluid passageway connecting a first port and one or more second ports. A sealing element seals against the tubular member. The shaft moves relative to the sealing sleeve between an open position in which the first port is in fluid communication with the second port and a closed position in which the sealing sleeve closes the first port. An anchor secures the sealing sleeve relative to the tubular member to permit the shaft to move from the open position to the closed position.

Abstract: Systems and methods of determining parameter values in a downhole environment are described. An example method of determining a parameter value using calibration information is described. The calibration information corresponding to different parameter ranges in a downhole environment. The method includes determining a parameter range in the downhole environment using a controller and obtaining first calibration information or second calibration information based on the parameter range. The first calibration information associated with a first parameter range and the second calibration information associated with a second parameter range. The method also includes receiving an output signal from a sensor associated with the parameter and using the obtained calibration information to determine the parameter value based on the output signal received.

Abstract: A technique provides a system and method utilizing a well system having a plurality of tools with actuatable components. The well system also comprises tracer elements which are unique with respect to corresponding tools of the well system. The tracer elements are positioned and oriented to open when physically engaged by the actuatable component of a corresponding tool. Released tracer material from the tracer element may be detected to confirm actuation of a specific tool in the well system.

Abstract: Method for quantitatively assessing connectivity for well pairs at varying frequencies. A time series of measurements (12) is chosen for each of the two wells such that the particular measurements will be sensitive to subsurface connectivity if it exists (11). The two time series may then be pre-processed by resampling to time intervals commensurate with response time between the two wells (13), detrending the measurements (14), and detecting and eliminating spiking noises (15). Then the time series are transformed to the frequency domain where coherence and phase between the two series are compared for varying frequencies (16). This comparison is used to make a determination of connectivity.