Abstract: A centralizing device (1) for an elongated body (16) which is located in a mousehole machine (2), the centralizing device (1) being at the upper portion of the mousehole machine (2), and the centralizing device (1) being supported and rotatable around a substantially horizontal axis of rotation (22) extending through the opening (10) of the mousehole machine, and the centralizing device (1) including two centralizing bows (24) located on radially opposite sides of the axis of rotation (22).

Abstract: A technique provides an orientation system combined with downhole equipment used in a well. An orientation device is mounted in the downhole equipment, e.g. a bottom hole assembly, for actuation during angular displacement of the downhole equipment. A sensor is mounted to cooperate with the orientation device in detecting the angular displacement.

Abstract: Methods and apparatus for determining the direction of borehole azimuthal offset and the borehole radius of curvature. Rotation rate of a borehole assembly is measured and mathematically converted into azimuthal torque imparted to the borehole assembly. Relative azimuthal offset is determined from variations in azimuthal torque over a rotation cycle of the borehole assembly. Relative radius of curvature is obtained from the magnitude of azimuthal torque over a rotation cycle. Relative azimuthal offset is converted to true azimuthal offset using an independent reference angle measurement. Relative borehole curvature is converted to true radius of curvature using a calibration constant determined in known borehole conditions.

Abstract: Aspects of this invention include methods for surveying a subterranean borehole. In one exemplary aspect, a change in borehole azimuth between first and second longitudinally spaced gravity measurement sensors may be determined directly from gravity measurements made by the sensors and a measured angular position between the sensors. The gravity measurement sensors are typically disposed to rotate freely with respect to one another about a longitudinal axis of the borehole. Gravity MWD measurements in accordance with the present invention may be advantageously made without imposing any relative rotational constraints on first and second gravity sensor sets. The present invention also advantageously provides for downhole processing of the change in azimuth between the first and second gravity sensor sets. As such, Gravity MWD measurements in accordance with this invention may be advantageously utilized in closed-loop steering control methods.

Abstract: An apparatus for use in a wellbore is disclosed that in one aspect includes a drilling assembly configured for use in drilling the wellbore, a liner disposed outside a portion of the drilling assembly that includes a feature at a selected location of the liner, and a liner orientation sensor for providing signals representative of the displacement or movement of the feature relative to the drilling assembly.

Abstract: Methods and related systems are described for use for determining orientation of a measurement tool in a cased borehole. The measurement tool is deployed in a cased section of a borehole. The tool includes a volume containing a reference fluid having a first density, and a marker within the fluid having a different density. The position of the marker within volume containing the reference fluid is senses, and orientation information of the measurement tool is determined based at least in part on combining information relating to the position of the marker with prior recorded data representing orientation measurements made while the section of the borehole was not yet cased.

Abstract: Exhaust pressure from at least one actuator (34,36) which can tilt joint 6 of a bottom hole assembly 4 can be utilized to determine the direction 26 tiltable joint 6 is pointing (e.g., orientation, angular displacement, and/or inclination and azimuth). In one embodiment, a known exhaust pressure can be correlated to a known orientation and/or angular displacement, and the measured exhaust pressure can be compared to the known exhaust pressure to determine the orientation and/or angular displacement. In another embodiment, the flow rate of fluid exhausted from an actuator (34,36) can be derived from the exhaust pressure. The exhaust flow rate can then be used to calculate the state of actuation, which can allow determination of the angular displacement of the tiltable joint 6. Orientation and/or angular displacement with respect to the bottom hole assembly 4 can be resolved into an inclination and azimuth with respect to a formation 14.

Abstract: A tool system for monitoring a flow of liquid within a borehole. The tool system comprises a plurality of tools disposed on a longitudinal axis of the tool system. The plurality of tools comprises at least a first injector tool for ejecting in the borehole a tracer and a detector tool to detect the ejected tracer. The tool system further comprises a standard digital bus traversing at least a portion of each tool of the plurality of tools. The standard digital bus allows a communication between each tool of the plurality of tools.

Abstract: Apparatus having a fiber optic tether disposed in coiled tubing for communicating information between downhole tools and sensors and surface equipment and methods of operating such equipment. Wellbore operations performed using the fiber optic enabled coiled tubing apparatus includes transmitting control signals from the surface equipment to the downhole equipment over the fiber optic tether, transmitting information gathered from at least one downhole sensor to the surface equipment over the fiber optic tether, or collecting information by measuring an optical property observed on the fiber optic tether. The downhole tools or sensors connected to the fiber optic tether may either include devices that manipulate or respond to optical signal directly or tools or sensors that operate according to conventional principles.

Abstract: A pressure orienting swivel arrangement including a weight assembly and a pin adapter reactably interengagable with the weight assembly to orient the pin adapter to the weight assembly. A pressure orienting swivel arrangement including a housing, a spring compression mandrel within the housing, a spring disposed about the spring compression mandrel, a weight assembly rotatably supported in the housing, and a pin adaptor rotatably supported within the housing and reactably interengagable with the weight assembly to accept a torque from the weight assembly. A method for orienting a downhole tool.

Abstract: A casing annulus is remediated by inserting a hose into a casing annulus, the hose having a nozzle on its lower end. An acoustic signal is directed into the annulus. A sensor in the hose receives the acoustic signal and transmits data from the sensor to the surface. The data represents the acoustic signal arrival time to the sensor, and an analyzer estimates the sensor depth based on the data. The hose is inserted from a reel into a wellhead above the annulus. An electrical transducer mechanically coupled to the hose creates the acoustic signal. The signal is propagated along the hose and transferred to the fluid in the annulus, where it then propagates further into the annulus. The transducer can be installed on a hose roller along which the hose is fed into the wellhead.

Abstract: Apparatus and method for a retrievable plug in coil tubing. A plug is disposed within a tubing and is set within the tubing by an anchoring element placed in gripping engagement with the tubing. The plug also has seal elements disposed therein that are placed in sealing engagement with the tubing. An orientation element on the plug positions the plug within the tubing with respect to the seam of the tubing.

Abstract: A technique is employed to shift a well tool located in a wellbore. A shifting tool is moved downhole into proximity with a well tool that is to be shifted. The shifting tool comprises one or more engagement members that enable engagement with any of a variety of well tools having a variety of sizes. A sensor system provides an indication as to when the shifting tool is moved into proximity with a specific well tool.

Abstract: A monitoring system is used to monitor the location and orientation of a downhole tool assembly by detecting an output signal. The downhole tool assembly has a beacon assembly with one or more configurable operation parameters. A transmitting assembly transmits a modulated instruction signal to the beacon assembly to configure the operation parameters. The modulated instruction signal is processed by the beacon assembly and the operation parameter is configured. The transmitting assembly may be separate from the monitoring system and have an input assembly. The input assembly allows the operator to input predetermined operation parameters into the transmitting assembly that are then transmitted to the beacon assembly. In a preferred embodiment, the configurable operation parameters may include the intensity and/or frequency of the output signal, the calibration and resolution of orientation sensors, and the rate at which data is transmitted from the beacon assembly.

Abstract: A tool that is usable in a well and may include an operator, a switch, a resilient device and an indexer. The switch may be configured to selectively communicate a first force to the operator, thereby actuating the tool. The resilient device may exert a second force. The indexer may cycle through a sequence of positions in response to alternating between the second force and a third force. The sequence includes a predetermined position configured to actuate the switch, thereby communicating the first force to the operator to actuate the tool.

Abstract: A device and method for inspecting an inspection object of in the vicinity of a further object, both of electrically conductive material, the device comprising a transmitter/receiver arrangement for generating an electromagnetic field in the inspection object, and for measuring a signal indicative of a transient eddy current which is generated in the inspection object by the electromagnetic field, wherein the device further comprises a magnetic shield means, providing at least a partial magnetic shield for the transmitter/receiver arrangement in a direction other than a measurement direction; use of the device from inside an annulus between an inner and an outer tubular, and a method of operating a hydrocarbon well having a well completion, and inspecting the well completion from inside an annulus.

Abstract: A downhole tool includes a mandrel, an inner sleeve, and an outer housing. The inner sleeve being rotatable relative to the outer housing and the mandrel being rotatable relative to the inner sleeve and the outer housings. The outer surface of the inner sleeve includes more than one selected position organized in at least one set. At least two of the selected positions include magnets. The downhole tool also includes at least one magnetic sensor to sense at least one of the amplitude and polarity of the magnetic field for the selected positions and to transmit a signal indicative of the sensed magnetic field. The downhole tool also includes an electronics system to process the sensor signal to determine a magnet reference position of the inner sleeve relative to the outer housing.

Abstract: A method for determining a rate of change of longitudinal direction of a subterranean borehole includes positioning a downhole tool in a borehole, the tool including first and second longitudinally spaced surveying devices disposed thereon. The method further includes causing the surveying devices to measure longitudinal directions of the borehole at first and second longitudinal positions and processing the longitudinal directions of the borehole to determine the rate of change of longitudinal direction of the borehole between the first and second positions. The method may further include processing the measured rate of change of longitudinal direction of the borehole and a predetermined rate of change of longitudinal direction to control the direction of drilling of the subterranean borehole. Exemplary embodiments of this invention tend to minimize the need for communication between a drilling operator and the bottom hole assembly, thereby advantageously preserving downhole communication bandwidth.

Abstract: A signature element is attached to a downhole cable or other protected equipment and the signal from a signature position detector is used, at least in part, to control the orientation of a directed perforating device or other directional device. Signal emitting sources can include a radioactive material added to an encapsulating composition of a downhole cable.

Abstract: Electrically powered electromagnetic field source beacons installed in a reference well in combination with a down-hole measurement while drilling (MWD) electronic survey instrument near the drill bit in the borehole being drilled permit distance and direction measurements for drilling guidance. Each magnetic field source beacon consists of a coil of wire wound on a steel coupling between two lengths of steel tubing in the reference well, and powered by an electronic package. Control circuitry in the electronic package continuously “listens” for, and recognizes, a “start” signal that is initiated by the driller. After a “start” signal has been received, the beacon is energized for a short time interval during which an electromagnetic field is generated, which is measured by the MWD apparatus.

Abstract: Methods of generating radial survey images of a borehole and methods of orienting downhole operational tools are disclosed. The disclosed techniques are used to generate a radial survey of the borehole in the form of one or more rose-plots and/or a radial image of the borehole and surrounding area that can be used to properly orient downhole operational tools in the desired direction. The tool string includes, from the top to bottom, a telemetry module, a non-rotating centralizer, a motor module, an imaging sonde used to survey the borehole, a rotating centralizer and a downhole operational tool. The motor module can be used to rotate the imaging sonde to generate the radial survey and then rotate the downhole operational tool to the desired direction based upon a review of the radial survey.

Abstract: A rod guide is provided for use in a rotating rod string (12) for powering a progressive cavity pump (14) for pumping downhole fluids through tubing (16) to the surface. The rod guide includes a rotor sleeve (20) secured to the rod string and having a plurality of circumferentially spaced exterior surfaces (22) each positioned substantially along an exterior of a cylinder. The rotor sleeve also includes one or more stop surfaces (24) for limiting axial movement of a stator sleeve (40) with respect to the rotor sleeve, and two or more axially extending cavities (26) each extending from a bottommost surface to an opposing uppermost surface of the rotor sleeve and passing through the one or more stop surfaces. Stator sleeve (40) surrounds the rotor sleeve and has an interior surface (42) for engaging the plurality of circumferentially spaced exterior surfaces of the rotor sleeve, and a plurality of ribs (44) extending outward from two or more outer cylindrical surface portions (44) of the stator sleeve.

Abstract: A method of drilling a well. The method includes calculating an estimated formation dip angle, wherein said estimated formation dip angle being based on offset well data, seismic data, core data, pressure data. Next, the method includes drilling a well with a logging while drilling means so that real time logging data is generated along with drilling data and calculating an instantaneous formation dip angle. Next, real time logging data is obtained and a target formation window is projected ahead of the well path that includes a top of formation and a bottom formation. The method includes monitoring the real time logging and drilling data and drilling the well through the target formation window. The method further includes changing the estimated instantaneous formation dip based on the obtained data and adjusting the target formation top and bottom window.

Abstract: An apparatus for performing operations on an offshore well includes a subsea wellhead assembly. A riser extends from the subsea wellhead assembly to a surface vessel. A tool connects to a running string and is lowered through the riser into the wellhead assembly for performing operations at the wellhead assembly. A subsea controller is located adjacent the subsea wellhead assembly. The subsea controller controls the operation of the tool. A surface controller is positioned on the surface vessel, and is in communication with the subsea controller via a control line extending downward from the surface controller to the subsea controller. The control line extends downward from the surface controller along an exterior of the riser.

Abstract: A technique provides an orientation system combined with downhole equipment used in a well. An orientation device is mounted in the downhole equipment, e.g. a bottom hole assembly, for actuation during angular displacement of the downhole equipment. A sensor is mounted to cooperate with the orientation device in detecting the angular displacement.

Abstract: An apparatus for use in a wellbore is disclosed that in one aspect includes a drilling assembly configured for use in drilling the wellbore, a liner disposed outside a portion of the drilling assembly that includes a feature at a selected location of the liner, and a liner orientation sensor for providing signals representative of the displacement or movement of the feature relative to the drilling assembly.

Abstract: A technique is provided to form perforations in a wellbore. The formation of perforations is carefully controlled by a perforating device to create a series of sequential perforations in a desired arrangement. The perforating device is lowered to a desired location in the wellbore and then moved incrementally to enable sequential perforations in the desired arrangement.

Abstract: A downhole tool for use within a well has a body with a first downhole fluid passage provided in the body. The first downhole fluid passage has an upper inlet and a lower outlet. A first sleeve member is slidably mounted to the body such that the first sleeve member is movable between a first position in which the first sleeve member extends from the body and a second position in which the first sleeve member is substantially retracted into the first downhole fluid passage of the body. A guide adapted to guide an object travelling within the first downhole fluid passage to the first sleeve member is provided.

Abstract: The present invention relates to an apparatus and method for using that apparatus to orient a perforating gun or system to minimize or eliminate the damage which may be caused to exterior control conduits, conductors or devices, or to adjacent interior well control lines, conduits or tubing by attaching the perforating system to a device which has a resilient cam or guide which engages a slot formed on the interior of a specially fabricated tubular member attached at a spaced distance from the perforating systems blast and which is so oriented as to permit the attachment of the lines or conduits or devices in the opposite radial direction from the blast of the perforating system.

Abstract: A method of sampling fluid from a subterranean formation includes positioning a first tool having a heater in a borehole so that the heater is adjacent a portion of the subterranean formation: heating with the heater the portion of the subterranean formation; removing the first tool from the borehole; orienting a second tool having a sampling probe in the borehole so that the sampling probe is to contact a portion of the subterranean formation heater by the heater; and obtaining via the sampling probe a fluid sample from the portion of the subterranean formation heater by the heater.

Abstract: A method and apparatus for forming multiple lateral passages from a wellbore into a subsurface earth formation to facilitate enhancement of the production of oil, gas, heavy oil or minerals from the formation. A plurality of lateral passages are formed from a wellbore into a subsurface formation through the use of a single-run passage forming tool to minimize rig time and associated costs. A downhole indexing tool is positioned downhole and has indexing sections for positioning and indexing of a downhole well service tool and establishes precise radial orientation and location of the tool for its well servicing operation. Sequential unidirectional rotational indexing is accomplished by an indexing control stinger having a J-slot indexing system defining a circumferential slot section defining a desired number of indexing positions that are sequenced responsive to linear reciprocating movement of the indexing control stinger.

Abstract: In accordance with the teachings of the present invention, a method is provided for preventing formation of sludge in a subsurface cavity having particulate laden fluid disposed therein. The method includes positioning a downhole device having a fluid agitator into the fluid of the subsurface cavity and agitating the fluid using the fluid agitator.

Abstract: Downhole tools, such as a sliding sleeve or an openhole type packer, include position indicators. The position indicators can include one or more magnets disposed in predetermined positions in the outer housing and the insert of the sliding sleeve. A casing collar locator (CCL) can be used to detect the magnets and determine the relative positions of the housing magnets and insert magnets. The relative positions of the magnets can be used to determine the operational condition of the downhole tool, i.e., whether a sliding sleeve is open or closed or how much a sealing element of an openhole type packer had to expand to seal an annulus.

Abstract: A communication tool apparatus is described which is adapted to provide selective communication of control fluid through a downhole device such as a safety valve. The downhole safety valve is a tubing retrievable subsurface safety valve (“TRSSSV”). The communication tool may be run downhole and within the TRSSSV. Once within the TRSSSV, the communication tool apparatus activates a cutting device within the TRSSSV such that communication of control fluid through the TRSSSV is possible. A replacement safety valve run on a wireline may then be inserted into the TRSSSV and be operated via the control fluid line, as a new communication path created by the communication tool described herein. A method of using the communication tool apparatus is also described.

Abstract: System and method of controlling a trajectory of a wellbore comprises conveying a drilling assembly in the wellbore by a rotatable tubular member. The drilling assembly includes a drill bit at an end thereof that is rotatable by a drilling motor carried by the drilling assembly. The drilling assembly has a first adjustable stabilizer and an second stabilizer spaced apart from the first adjustable stabilizer. The first adjustable stabilizer having set of ribs spaced around the stabilizer, with each rib being independently radially extendable. The position of a first center of the first adjustable stabilizer is adjusted in the wellbore relative to a second center of the second stabilizer in the wellbore for controlling the trajectory of the wellbore.

Abstract: The purpose of the method of the present invention is to provide an improved method and an improved apparatus, to displace light, medium, or viscous hydrocarbon fluid, which may be contaminated with earthen solids, from the subterranean hydrocarbon reservoir to a hydrocarbon fluid storage tank or other handling facilities on ground surface, by means of oil well production. The method is intended for use in cold primary hydrocarbon production or thermally stimulated hydrocarbon production from vertical, slant, whipstocked, or horizontal oil wells. The production system does not employ moving subsurface mechanical components.

Abstract: A method for estimating an azimuthal dependence of a parameter of a borehole using logging sensor measurements acquired as a function of azimuth of the logging sensors is provided. The method includes acquiring at least one logging sensor measurement and a corresponding azimuth from a downhole tool. The method further includes processing a convolution of the logging sensor measurement and corresponding azimuth with a predetermined filter to determine convolved logging sensor data for at least one azimuthal position. Certain embodiments of this invention may be advantageously utilized in LWD imaging applications to provide for superior image resolution and noise rejection as compared to prior art imaging techniques.

Abstract: A rotational alignment system determines the angular relationship between two or more elements of a drill string using one or more sensors that detect one or more reference objects positioned on the drill string. A control unit determines the rotational or angular offset between two or more elements on the drill string using measurements made by the sensor(s). In one application, rotational offset values are used by a surface logging computer to correlate sensor data provided by a logging tool.

Abstract: Acoustic transducers configured with integrated electronics technology are adapted to digitize signal data close to the transducer. The transducers are packaged with a reduced number of elements and sealed for exposure to harsh environments, without oil compensation. A transducer assembly includes a frame, an acoustic transducer element disposed on the frame, and an electronics module disposed on the frame and linked to the acoustic transducer element. The pressure and temperature tolerant electronics module is adapted to process a signal associated with the transducer element.

Abstract: A downhole tool for use in a well bore comprises an onboard navigation system for determining the location of the tool within the well bore, wherein the tool is moved along at least a partial length of the well bore via an external force. A method of locating a downhole tool in a well bore comprises deploying the tool along at least a partial length of the well bore via an external force, and self-determining the location of the tool without receiving communications from the surface. In an embodiment, the tool is a well bore zonal isolation device.

Abstract: A monitoring system is used to monitor the location and orientation of a downhole tool assembly by detecting an output signal. The downhole tool assembly has a beacon assembly with one or more configurable operation parameters. A transmitting assembly transmits an operation instruction signal to the beacon assembly to configure the operation parameters. The detected operation instruction signal is processed by the beacon assembly and the operation parameter is configured. The transmitting assembly may be separate from the monitoring system and have an input assembly. The input assembly allows the operator to input predetermined operation parameters into the transmitting assembly that are then transmitted to the beacon assembly. In a preferred embodiment, the configurable operation parameters may include the intensity and/or frequency of the output signal, the calibration and resolution of orientation sensors, and the rate at which data is transmitted from the beacon assembly.

Abstract: The present invention relates to a downhole method and apparatus for locating a window in a wellbore casing and determining the depth and orientation of said window. Apparatus of the present invention comprises a body (4) and a window engaging member (6) mounted on said body (4) so as to be movable between a retracted position and an extended position. The engaging member (6) is adapted to project into a wellbore window when in the extended position during use and is further adapted to engage with a first position of said window in such a way that, when pressed against said window portion, the engaging member (6) tends to slide along wellbore edge defining said window portion so as to locate the engaging member (6) centrally in said window portion before preventing movement of the apparatus in the direction of pressing. The invention thereby allows the depth and orientation of a window in a wellbore to be determined.

Abstract: In one aspect of the present invention, a drill string has a drill bit with a body intermediate a shank and a working face. The working face has a plurality of blades converging at a center of the working surface and diverging towards a gauge of the working face. At least one blade has a cutting element with a carbide substrate bonded to a diamond working end with a pointed geometry. The diamond working end also has a central axis which intersects an apex of the pointed geometry. The axis is oriented between a 25 and 85 degree positive rake angle.

Abstract: A method of servicing a well bore comprises deploying into the well bore a zonal isolation device operable to self-set at a sensed location, and self-setting the zonal isolation device to hold at the sensed location without receiving command communications from the surface, wherein the zonal isolation device is deployed along at least a partial length of the well bore via an external force. Another method of servicing comprises deploying into the well bore a tool operable to self-activate at one or more locations, and self-navigating the tool to determine the one or more locations without receiving communications from the surface, wherein the tool is moved along at least a partial length of the well bore via an external force.

Abstract: A method performing an operation in a subsea wellhead assembly through a riser extending between the wellhead assembly and a surface platform includes the step of connecting a surface blowout preventer to an upper portion of the riser. Then a tool is connected to a string of conduit. A control line is then connected to the tool, extended alongside the conduit. The tool and control line are lowered through the blowout preventer and riser. The method also includes the step of mounting a slick joint to an upper end of the conduit when the tool is near the wellhead assembly. The control line is then linked through the slick joint and extends to the surface platform. The method also includes the step of communicating with the tool via the control line and performing an operation in the wellhead assembly with the tool.

Abstract: A borehole tool positioning and measuring apparatus and its methods of use are provided. The apparatus and method can be used to centralize a logging tool in a wellbore, or position a logging tool at a desired relative alignment relative to the wellbore perimeter surface. The method and apparatuses can be used to determine useful information regarding borehole size and configuration. Various embodiments are useful for centralizing, eccentralizing, and otherwise positioning a borehole tool in a wellbore. Methods of determining borehole size and configuration measurements using a positioning apparatus are also provided.

Abstract: A nuclear sensor on a bottomhole assembly (BHA) makes measurements of a property of an earth formation during continued rotation of the BHA. Magnetometers that are susceptible to bias error are deployed on the BHA to make measurements of the magnetic toolface angle. A processor separates the sensor measurements into azimuthal sectors while compensating for inherent time delays in the electronics, non-uniform rotation, and bias.

Abstract: A method for determining a rate of change of longitudinal direction of a subterranean borehole is provided. The method includes positioning a downhole tool in a borehole, the tool including first and second surveying devices disposed thereon. The method further includes causing the surveying devices to measure a longitudinal direction of the borehole at first and second longitudinal positions and processing the longitudinal directions of the borehole at the first and second positions to determine the rate of change of longitudinal direction of the borehole between the first and second positions. The method may further include processing the measured rate of change of longitudinal direction of the borehole and a predetermined rate of change of longitudinal direction to control the direction of drilling of the subterranean borehole.

Abstract: A self orienting selectable locating collet including a collet having at least one deflectable finger; an orientation key positioned at the deflectable finger and being deflectable with the finger; and a collet profile disposed at an outside dimension of the collet. A method is also included.

Abstract: In accordance with the teachings of the present invention, a method is provided for preventing formation of sludge in a subsurface cavity having particulate laden fluid disposed therein. The method includes positioning a downhole device having a fluid agitator into the fluid of the subsurface cavity and agitating the fluid using the fluid agitator.