Abstract: Generally, the subject matter disclosed herein is directed to devices and methods for energizing and detecting a wave-energizable apparatus on an item movable with respect to a working surface of a drilling rig. One illustrative device disclosed herein includes at least one mat adapted to be positioned on a working surface of a drilling rig and a plurality of spaced-apart energizing apparatuses operatively coupled to the at least one mat. Additionally, each of the plurality of spaced apart energizing apparatuses of the disclosed device is adapted to energize a wave-energizable apparatus attached to an item that is movable adjacent to the mat and relative to the working surface.

Abstract: A system for positioning a wellbore tool in a wellbore intersecting a subterranean formation includes a tag embedded in the formation using a tag insertion device. The tag may be configured to transmit a signal that includes information. A wellbore tool may utilize a tag detection device to operatively link with the tag. This operative link may provide an indication of the relative position of the tag detection device or some other information.

Abstract: The present invention involves methods and apparatus for permanent downhole deployment of optical sensors. Specifically, optical sensors may be permanently deployed within a wellbore using a casing string. In one aspect, one or more optical sensors are disposed on, in, or within the casing string. The optical sensors may be attached to an outer surface of the casing string or to an inner surface of the casing string, as well as embedded within a wall of the casing string. The optical sensors are capable of measuring wellbore parameters during wellbore operations, including completion, production, and intervention operations.

Abstract: A method of locating a wellbore feature, comprising delivering a mechanical position determination tool into the wellbore, selectively causing an undulating curvature of the mechanical position determination tool in response to a change in a fluid pressure, moving the mechanical position determination tool along a longitudinal length of the wellbore, and sensing a change in resistance to continued movement of the mechanical position determination tool. A mechanical position location tool for a wellbore, comprising pressure actuated elements configured to cooperate to selectively provide an unactuated state in which the mechanical position location tool lies substantially along a longitudinal axis and the pressure actuated elements further configured to cooperate to selectively lie increasingly deviated from the longitudinal axis in response to a change in pressure applied to the mechanical position location tool.

Abstract: A system for communicating with downhole components is provided comprising at least one RFID device configured with an identification code. The system further includes a device conduit extending next to the downhole components and a device propulsion system configured to translate the RFID devices next to the downhole components to facilitate an exchange of information between the downhole component and the RFID device. The device conduit may include a check valve or a turn-around sub depending upon the application. In some cases, the exchange of information may trigger actuation of one or more of the downhole components. A method is also provide comprising providing a device conduit near downhole components, propelling an RFID device near to the downhole components via the device conduit and a device propulsion system, and exchanging information between the RFID device and the downhole components.

Abstract: A means of investigating the quality and/or nature of perforations in a downhole environment is disclosed. A ‘pecking’ finger and depth measuring probe that can be axially and radially displaced enables the perforation to be located and its depth determined, through sequentially pecking around the wall lining in patterns such as radial, axial, and spiral sequences. By swinging a pecking finger that supports a depth measuring probe or cable with a bullet or conically shaped tip and measuring the displacement of the finger, the edge and centre of the hole can be determined with the largest displacement being when the tip is fully in the hole. When this position has been determined, the depth measuring cable is deployed and the depth of the perforation can be established by both an increase in the force required to push the cable and by the displacement of the pecking finger as it is pushed back by the reaction forces on the cable.

Abstract: Certain embodiments described herein provide methods, systems and computer-readable media for determining at least one location of at least one wellbore casing within a wellbore conductor. Sensor measurements generated by at least one sensor within the conductor are provided, the measurements indicative of at least one location of the at least one casing within the conductor as a function of position along the conductor. In certain embodiments, a data memory stores the measurements. The at least one location of the at least one casing is calculated using the measurements and at least one geometric constraint. The at least one constraint originates at least in part from at least one physical parameter of the conductor, or at least one physical parameter of the at least one casing, or both. In certain embodiments, a computer system or computer-executable component calculates the at least one location of the at least one casing.

Abstract: Tubewaves are used to transmit an indication of the depth at which a condition is detected in a well. In particular, the depth is calculated based on the difference in arrival time at the surface of a first tubewave which propagates directly upward in the borehole and a second tubewave which initially travels downward and is then reflected upward. The tubewaves may be generated by a canister designed to implode at a certain pressure. The canister is carried downhole by gravity and the fluid being pumped. At a depth at which its pressure tolerance is exceeded, it implodes and generates the tubewaves. An analyzer at the surface detects the tubewaves and generates a pressure versus depth profile of the well. Canisters may be acoustically tagged in order to generate tubewaves having particular frequency and amplitude characteristics. Canisters may also be configured to produce multiple implosions.

Abstract: An indicator comprising a band having a first radial dimension; one or more protectors having a greater radial dimension and disposed sufficiently proximate the band to substantially avoid wear of the band during running of the indicator and method.

Abstract: A method of checking for restrictions in a string of tubing formed of a plurality of tubing sections. The method involves providing a profile in the tubing string, providing a drift member adapted to engage with the profile, passing the drift member through the tubing string, and determining whether the drift member has engaged with the profile prior to separating the tubing sections.

Abstract: A plunger has a transmitter that produces signals as the plunger moves in a well. The signals are pulses that are produced at a constant interval. The plunger signals are detected and used to determine the location, direction of travel and speed of the plunger in the well. In addition, the location or height of the liquid level is detected as is the arrival of the plunger at the well bottom.

Abstract: A downhole tool deployment apparatus is disclosed, which preferably includes at least an in-ground well casing, a depth determination device providing a hermetically sealed electronics compartment, tool attachment portions, and a first flow through core. The depth determination device is preferably configured for sliding communication with the well casing. The hermetically sealed electronics compartment secures a processor and a location sensing system, which communicates with the processor while interacting exclusively with features of the well casing to determine the location of the depth determination device within the well casing. A preferred embodiment further includes a well plug affixed to the tool attachment portion, the well plug includes a second flow through core capped with a core plug with a core plug release mechanism, which upon activation provides separation between the second flow through core and the core plug, allowing material to flow through said first and second flow through cores.

Abstract: Electromagnetic free point tools are configured to determine the free point of a downhole pipe in a wellbore utilizing the amplitude or phase change in a transmitted signal for stressed and unstressed pipe. Certain examples of electromagnetic free point tools comprise a housing, one or more transmitter coils, one or more receiver coils, each coil spaced apart from one another, a power source for applying an oscillating voltage to the one or more transmitter coils which then induces a current in the receiver coil(s), and electronics for measuring the induced current in the receiver coil(s). In another embodiment, at least one of the coils is axially adjustable in position within the tool to permit the relative distance between coils to be adjusted to optimize performance of the tool in various conditions. By measuring the amplitude or phase of the induced current relative to the oscillating voltage, a log of the amplitude or phase is generated while passing the tool through a length of unstressed pipe.

Abstract: A memory logging system for determining the status of a sliding sleeve valve disposed within the borehole. The sliding sleeve contains signal inducing devices. A logging tool is conveyed through the sliding sleeve and time intervals between sensor excursions induced by the sleeve's signal inducing devices are recorded and stored within the tool memory. These data are subsequently recovered when the tool is returned to the surface of the earth, and sensor excursion data are processed in a surface processor to ascertain relative axial positions of the sliding sleeve outer housing and the insert. The condition of the sliding sleeve is determined from these relative axial positions.

Abstract: A down-hole assembly used to locate an existing window in a main cased well bore and guide equipment through the window and into a lateral well bore after removal of a whip stock. The down-hole assembly includes a running tool with a convex section detachably connected to a concave section of a guide member. The running tool includes a window locator that locates the window. The window locator may contain a selectively reciprocating shear rod operatively associated with a stop/shear block to enable the window locator to locate a plurality of lateral well windows in a main well bore. The guide member includes an inclined or wedge shaped portion for guiding tools or equipment through the window and into the lateral well bore so that remedial work can be carried out.

Abstract: A location-and-rotation feedback tool that provides accurate feedback of the location and orientation of a well component during running operations in wells. The feedback tool device is adapted to be secured on a tool stem above a running tool and comprises a body, a circumferentially extending groove, and a hole in the groove that vents to the bore of a blowout preventer. The circumferential groove aligns with a fluid line port in the blowout preventer to provide location feedback via a fluid line pressure. The hole aligns with the fluid line port in the blowout preventer to provide rotation feedback via fluid line pressure.

Abstract: A well tool having a magnetically coupled position sensor. In operation of a well tool, relative displacement is produced between members of the well tool. A magnetically coupled position sensor includes one magnet assembly attached to a member for displacement therewith and another magnet assembly movably attached to the other member and magnetically coupled to the first magnet assembly for displacement therewith. The position sensor further includes a magnetically permeable material which increases a magnetic flux density between the magnet assemblies. The magnetically permeable material may be positioned between magnets of the magnet assemblies and/or spaced apart therefrom.

Abstract: An embodiment of a method of performing a wellbore operation in an oilfield comprises providing a bottom hole assembly on a conveyance, deploying the bottom hole assembly into the wellbore with the conveyance, determining the depth location of the bottomhole assembly in the wellbore utilizing a mechanical device, moving the bottom hole assembly to a desired location based on the determined depth, circulating a fluid from the oilfield to the bottomhole assembly, and performing at least one wellbore operation while the bottomhole assembly is deployed at the desired location.

Abstract: Downhole tools attached to a wireline are frequently used to perform well operations at a selected depth. However, the downhole tools may be placed at the incorrect depth if the well operator fails to account for creep, i.e. the movement of downhole tools after the wireline is stopped at the surface. This invention provides a method for determining when the well operator should account for creep. The invention further provides methods for determining the magnitude of creep when it is determined to be present. The subsequent positioning of downhole tools may be adjusted according to the magnitude of creep, thus preventing incorrect placement of downhole tools within the wellbore. The methods use equipment and logging data that are readily available during any wireline operation.

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: A method for placing ball sealers within a well formed within a subterranean formation for sealing holes in a casing of the well is carried out by performing at least one of two operations. The first operation involves providing a tag with at least one ball sealer or a carrier fluid containing the at least one ball sealer to facilitate monitoring of the location of the ball sealer. A tag monitoring device is provided within the well for monitoring the location of the tag. The ball sealer and carrier fluid with the tag are introduced downhole into the well. Information from the monitor device regarding the location of the tag is communicated to a remote monitoring location to the thereby provide an indication of the location of the tag within the well to a surface location. In the second operation a container is provided within the well at a known location downhole within the well. The container contains at least one ball sealer.

Abstract: Methods and devices are provided for accurately determining depths of certain structures in downhole strings. Locator tools comprise a shaft and a plurality of locator springs longitudinally mounted on the shaft. The locator springs are biased to expand and are configured to compress to allow the tool to traverse past restrictions in the downhole string. Each locator spring includes a locating pad that allows it to engage with an internal locating notch in the downhole string. The internal locating notch is sized to mate with the locator tool, i.e., to allow the locator springs to engage the internal locating notch. In this way, the depth of internal locating notches may be determined precisely and accurately by sensing engagement of the tool with the internal locating notch. Advantages of certain embodiments include more accurate depth determination, repeatable engagements of the tool, and reduced false engagements.

Abstract: A method for performing operations and for improving production in a well includes the steps of: providing radio identification devices at known locations in the well, and providing a reader device configured to read the identification devices, and to control the operations responsive to signals from the identification devices. The method also includes the steps of providing a process tool, and transporting the process tool and the reader device through the well. The reader device is programmed to control the process tool upon reception of a response signal from a selected identification device. The method can be used to perform perforating processes, packer setting processes, bridge plug setting processes, logging processes, inspection processes, chemical treating processes, and cleaning processes. In addition, the method can be performed dynamically by controlling the tool as it moves through the well, or statically by stopping the tool at a particular location within the well.

Abstract: An apparatus for use in deployment of downhole tools is disclosed. Preferably, the apparatus includes at least an in-ground well casing, a housing providing a hermetically sealed electronics compartment, a tool attachment portion, and a first flow through core. The housing is preferably configured for sliding communication with the well casing. The hermetically sealed electronics compartment secures a processor and a location sensing system, which communicates with the processor while interacting exclusively with features of the well casing to determine the location of the housing within the well casing. A preferred embodiment further includes a well plug affixed to the tool attachment portion, the well plug includes a second flow through core capped with a core plug with a core plug release mechanism, which upon activation provides separation between the second flow through core and the core plug, allowing material to flow through said first and second flow through cores.

Abstract: A method of expanding a tubular downhole comprises mounting a sensing device in a downhole tubular to be expanded, expanding at least a portion of the tubular and then engaging the sensing device with a retrieving device. The sensing device is then translated through the expanded tubular.

Abstract: A well tool having a magnetically coupled position sensor. In operation of a well tool, relative displacement is produced between members of the well tool. A magnetically coupled position sensor includes one magnet assembly attached to a member for displacement therewith and another magnet assembly movably attached to the other member and magnetically coupled to the first magnet assembly for displacement therewith. The position sensor further includes a magnetically permeable material which increases a magnetic flux density between the magnet assemblies. In another position sensor, one magnet assembly includes a magnet having a pole axis, the other magnet assembly includes another magnet having another pole axis, and the pole axes are aligned with each other.

Abstract: An apparatus for detecting a position of a component in an earth formation is disclosed. The apparatus includes: a transmitter configured to emit a first magnetic field into the earth formation and induce an electric current in the component, the transmitter having a first magnetic dipole extending in a first direction; and a receiver for detecting a second magnetic field generated by the component in response to the first magnetic field, the receiver having a second magnetic dipole extending in a second direction orthogonal to the first direction. A method and computer program product for detecting a position of a component in an earth formation is also disclosed.

Abstract: A methodology and apparatus for cutting shape(s) or profile(s) through well tubular(s), or for completely circumferentially severing through multiple tubulars, including all tubing, pipe, casing, liners, cement, other material encountered in tubular annuli. This rigless apparatus utilizes a computer-controlled, downhole robotic three-axis rotary mill to effectively generate a shape(s) or profile(s) through, or to completely sever in a 360 degree horizontal plane wells with multiple, nested strings of tubulars whether the tubulars are concentrically aligned or eccentrically aligned. This is useful for well abandonment and decommissioning where complete severance is necessitated and explosives are prohibited, or in situations requiring a precise window or other shape to be cut through a single tubular or plurality of tubulars.

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 method and an apparatus for activating an event if an object has undergone a pattern of motion with alternating motion and standstill which corresponds to a predetermined sequence of motions, in which all forms of motion are included.

Abstract: A methodology and apparatus for cutting shape(s) or profile(s) through well tubular(s), or for completely circumferentially severing a well through multiple tubulars, including all tubing, pipe, casing, liners, cement, other material encountered in tubular annuli. This rigless apparatus utilizes a computer-controlled, downhole robotic three-axis rotary mill to effectively generate a shape(s) or profile(s) through, or to completely sever in a 360 degree horizontal plane wells with multiple, nested strings of tubulars. This is useful for well abandonment and decommissioning where complete severance is necessitated and explosives are prohibited, or in situations requiring a precise window or other shape to be cut through a single tubular or plurality of tubulars.

Abstract: A depth control system for maintaining a tubing conveyed tool in a desired location in a cased wellbore during wellbore operations performed with the tool includes a bottom hole assembly carried by a tubing, the bottom hole assembly including a tool and an anchoring device. A method for maintaining a tool at a desired depth in a cased wellbore while performing wellbore operations with the tool includes the steps of conveying a tool and an anchoring device on a tubing to a desired depth in a wellbore having a casing, operating the tool to perform a wellbore operation and actuating the anchoring device to engage the casing and maintain the tool at the desired depth.

Abstract: A method and apparatus for actuating a downhole tool at a desired location. A reciprocating hydraulic slickline pump with a locator is provided. The pump comprises a pump member. The pump member is reciprocated axially by slickline in order to form an upstroke and downstroke. The pump is configured such that it pressurizes fluid within a workstring assembly during the pump's downstroke.

Abstract: A magneto-optic sensor for oilfield application, the sensor (1, 1?, 101, 101?) receives an incident beam IB, IBA, IBB, IBC, IBD and comprises a polarizing element (3, 103) for providing a determined state of polarization beam and a Faraday rotator (4, 104) for providing a response beam having a modified state of polarization. The sensor provides a response beam (RB, RBA, RBB, RBC, RBD having an intensity dependent on an external magnetic field representative of a particular characteristic of a well-bore casing CC, CR applied on the Faraday rotator (4, 104).

Abstract: An instrument, such as a wall-thickness, rod-wear, or pitting sensor, can monitor tubing as a field service crew extracts the tubing from an oil well or inserts the tubing into the well. A digital system can process data from the instrument to improve the data's fidelity, quality, or usefulness. Digital signal processing can comprise filtering or otherwise manipulating the data to provide refined data that a person or machine can readily interpret. For example, a graphical representation of the refined data can help an operator evaluate whether a segment of tubing is fit for continued service. Processing tubing data can comprise applying a flexible level of filtering, smoothing, or averaging to the data, wherein the level changes based on a criterion or according to a rule. The level can vary in response to a change in tubing speed, noise in the raw data, or some other parameter.

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 tubing punch and setting tool (TPST), operating on a single run for improved well bore intervention. The tool includes a setting tool for connecting to and setting a reference tool in a tubing string, a punch tool for punching holes in the tubing string wall, and actuation means to trigger the sequencing of the setting tool and the punch tool. The tool can be run on wireline, e-line or coiled tubing and allows a reference tool to be run and set on the same trip as punching holes in the tubing string. An embodiment is described wherein the reference tool is an anchor tool. With the distance known accurately between the anchor tool and the punched holes, a shortened retrofit gas lift straddle can be deployed.

Abstract: A method of checking for restrictions in a string of tubing formed of a plurality of tubing sections. The method involves providing a profile in the tubing string, providing a drift member adapted to engage with the profile, passing the drift member through the tubing string, and determining whether the drift member has engaged with the profile prior to separating the tubing sections.

Abstract: A deployment device for controlling rate of movement of an instrument inside a conduit includes a mandrel having a coupling to affix the deployment device to the instrument and a controllable brake disposed in the mandrel, the brake controllably actuatable to maintain the mandrel and instrument at a selected speed within the conduit.

Abstract: Downhole systems and methods including tags configured to provide distinguishable identifiers are set for selective release to a subsurface location. Sources/sensors in the wellbore are activated to detect the tags at a subsurface location, and signal data associated with the detected tags is conveyed to the surface.

Abstract: A technique provides a system and method to verify attachment of a fishing tool with a downhole well tool. The fishing tool comprises a latching mechanism that latches onto the well tool to be retrieved. The fishing tool also comprises a detection device to verify connection of the latching mechanism. The detection device provides a signal uphole to verify attachment to the well tool.

Abstract: A downhole system employing a crossover tool includes an actuator in operable communication with the crossover tool; a controller in operable communication with the actuator; a wired pipe in operable communication with the controller; and a control device in operable communication with the wired pipe and method.

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 and method for measuring depth, velocity, or both depth and velocity of instrumentation within a wellbore is provided. The apparatus includes a downhole portion movable within the wellbore in a direction generally parallel to the wellbore. The apparatus further includes a first acceleration sensor mounted at a first position within the downhole portion. The first acceleration sensor generates a first signal indicative of a first acceleration in a first direction generally parallel to the wellbore at the first position. The apparatus further includes a second acceleration sensor mounted at a second position within the downhole portion. The second acceleration sensor generates a second signal indicative of a second acceleration in a second direction generally parallel to the wellbore at the second position. The apparatus further includes a bend sensor generating a third signal indicative of an amount of bend of at least a portion of the downhole portion.

Abstract: A pair of elongated crossed coils is deployed in a first borehole and an instrument containing magnetic field sensors is deployed in a second borehole. The crossed coils are energized in quadrature by AC currents producing a rotating, elliptically polarized magnetic field at the second borehole. Mathematical analysis of the magnetic field sensor readings determines the location of the second borehole relative to the first. Both the distance and the rotational direction to the second borehole are determined as a function of depth of the sensors relative to that of the pair of crossed coils. Twisting of the long coil in the borehole is evaluated and the relative distance between the boreholes and the corrections needed due to such twisting are determined.

Abstract: A wireless casing collar locator includes a pipe coupling detector configured to be conveyed through a wellbore. A detection device is associated with the pipe coupling detector. The detection device generates an output indicative of detection of a pipe coupling in response to the output of the pipe coupling detector. The locator includes an acoustic transmitter functionally associated with the detection device. The transmitter is configured to apply an acoustic impulse to a conveyance device used to move the locator along the wellbore in response to communication to the transmitter of the output of the detection device. A surface receiver and processing unit used to convert acoustic energy into electrical energy for processing in real time to determine the location of the pipe detector in wellbores.

Abstract: A system and a method for adjusting the length of a cable between downhole sensors. The length adjustment system comprises a housing and at least one deforming member configured to translate relative to the housing. An actuator may be coupled to the deforming member and configured to translate the deforming member. The cable is deformed with one or more arcuate deformations, thereby reducing the length of the cable as measured relative to a straight line.

Abstract: Embodiments of the present invention generally relates to methods and apparatus for operating an artificial lift well. In one embodiment, the well is operated between an on cycle and an off cycle. Preferably, the off cycle is determined by detecting an increase in the pressure differential between the casing pressure and the tubing pressure. In another embodiment, the well is optimized by measuring the production of the well in one cycle of operation. The measured production is compared to the production of a previous cycle. A controller then optimizes the well based on the increase or decrease of the production from the previous cycle.

Abstract: A method, apparatus and system for predicting the formation pressure ahead of a bit in a well, which includes using measurements taken in shales and permeable formations at or near the bit together with centriod calculations to improve models predicting what the pressures ahead of the bit will be.

Abstract: A method of checking for restrictions in a string of tubing formed of a plurality of tubing sections. The method involves providing a profile in the tubing string, providing a drift member adapted to engage with the profile, passing the drift member through the tubing string, and determining whether the drift member has engaged with the profile prior to separating the tubing sections.