Abstract: The disclosed device provides a high-accuracy plunger arrival detection system comprising a low-power magnetometer with high sensitivity and which is capable of sampling low or high intensity magnetic fields. The device processes gathered data from sensors, stores at least some processed data in memory, executes a trending algorithm which compares the magnetic field of the plunger to the ambient magnetic field or a predetermined set of initialization values, and generates an output which is relayed to a well controller. An output signal may be via hard wire, RF, wireless or other known means. In addition, the implementation of two sensing devices mounted in series and in spaced relation to each other, can provide for an actual plunger average velocity. An actual plunger average velocity, as opposed to approximate average velocity, can be used to better optimize well control and improve safety of the overall well production system.

Abstract: A system for locating a downhole apparatus comprises a wellbore having an interior pressure cavity, wherein the apparatus is disposed in the pressure cavity, a magnetic device for generating a magnetic field in the pressure cavity, and a magnetic field indicator disposed external to the pressure cavity, the magnetic field indicator responsive to the magnetic field in the pressure cavity, wherein the magnetic field is indicative of a position of the apparatus in the pressure cavity.

Abstract: The present invention is directed to methods for assessing flow-induced electrostatic energy in an oil and/or gas well wherein electric current or electrostatic potential or both are measured to produce data correlating to at least one flow characteristic of a tubular segment in the well. In some embodiments, electric current and electrostatic potential are produced separately for a plurality of segments, and measured. The system further may adjust at least one flow characteristic of a segment of the well to increase hydrocarbon production from the well.

Abstract: A method of monitoring fluid flow in a borehole includes measuring acoustics at a plurality of locations along a downhole assembly in a borehole and calculating a fluid flow rate at the plurality of locations along the downhole assembly based on measuring the acoustics at the plurality of locations.

Abstract: Apparatuses and methods for retrieving a tool or bottom hole assembly. The apparatus may include a latching device that couples to a tool or bottom hole assembly to be retrieved and at least one seal extending radially from the apparatus to engage an inner diameter of a tubular, such as a casing string. A pump inlet is disposed in or through an outer surface of the apparatus uphole of the at least one seal. A pump outlet is disposed in or through an outer surface of the apparatus downhole of the at least one seal. The apparatus may also include a pump for pumping a drilling fluid from the pump inlet to the pump outlet in order to generate a differential pressure across the at least one seal and provide a hydraulic force to effect retrieval of the tool or bottom hole assembly.

Abstract: A differential pressure indicator (DPI) for use with a downhole isolation valve includes a tubular mandrel for assembly as part of a casing string and for receiving a tubular string. The mandrel has a stop shoulder and a piston shoulder. The DPI further includes a tubular housing for assembly as part of the casing string and for receiving the tubular string. The housing is movable relative to the mandrel between an extended position and a retracted position and has a stop shoulder and a piston shoulder. The DPI further includes a hydraulic chamber formed between the piston shoulders and a coupling in communication with the hydraulic chamber and for connection to a sensing line. The housing is movable relative to the mandrel and to the extended position in response to tension exerted on the DPI.

Abstract: A matrix acidizing monitoring system wherein a sensor array is operably associated with a matrix acidizing bottom hole assembly and contains first and second sets of sensors that detect a matrix acidizing operational parameter at different times at one or more particular locations along the wellbore. This allows the effectiveness of the acidizing to be modeled.

Abstract: A system and method for reducing borehole effects in a borehole within a subterranean formation is disclosed. The apparatus includes a fluid excluder, which includes a sleeve body and a sleeve opening defined by the sleeve body. The sleeve may be sized to fit around an induction tool. The sleeve body may include a fluid passageway therethrough, which may divert drilling fluids when the apparatus is deployed downhole. The apparatus may further include an electrode disposed within the fluid passageway for reducing the electrical current in the drilling fluid and thereby improve the readings obtained by logging devices.

Abstract: A shear tester for in-situ determination of rock formation geomechanical properties is provided. The tester has a radially expandable cylindrical membrane, a metal sheath covering at least a portion of the outer surface of the membrane, at least one stud fixed on the sheath, at least one cone fixed on each of the at least one stud, and a piston operable to apply an upward axial force on the metal sheath. A device for the same use comprises the shear tester and a pressuremeter. A method of using the shear tester comprises applying a normal force to the formation by expanding the membrane until at least one of the at least one cone penetrates the rock formation and applying an upward axial force to the at least one of the at least one cone by operating the piston until at least a portion of the rock formation shears.

Abstract: Apparatuses and methods useable in drilling installations having a mud loop for detecting ongoing or imminent kick events are provided. An apparatus includes a first sensor configured to measure a input mud flow pumped into the well, and a second sensor configured to measure a variation of a return mud flow emerging from the well. The apparatus further includes a controller connected to the first sensor, and to the second sensor. The controller is configured to identify an ongoing or imminent kick event based on monitoring and comparing an evolution of the input mud flow as measured by the first sensor and an evolution of the return mud flow as inferred based on measurements received from the second sensor. Additionally, a third sensor can be included in the apparatus to confirm the conclusion made by the controller before alerting the user that a kick has likely occurred.

Abstract: There are provided high power laser perforation, hydraulic fracturing systems, tools and methods for the stimulation and recovery of energy sources, such as hydrocarbons, from a formation. These systems, tools and methods provide predetermined laser beam energy patterns, to provide for the down hole volumetric removal of custom geometries of materials, sealing of perforations, reperorations, refractures and other downhole actives.

Abstract: A downhole disconnect device for disconnecting an intervention tool string from a wireline, includes: a tubular body having a first part directly or indirectly coupleable to the wireline and a second part connectable directly or indirectly to an intervention tool string; an actuator for disconnecting the second part of the tubular body from the first part of the tubular body; at least one sensor to detect when the tool string is stuck in use and to produce an output signal accordingly; a controller configured to receive the output signal and selectively operate the actuator accordingly; and a power source. The tubular body is adapted to house the actuator, sensor, controller and power source and the device further comprises a timer configured to delay operation of the actuator by a predetermined time on receipt of the output signal from the sensor. There is also a method of operating the downhole disconnect device.

Abstract: Among other things, there are disclosed embodiments of devices, suitable for incorporation into well-logging tools, for the in situ measurement of the acoustic impedance of a fluid in the well bore, such as drilling mud. The device includes a sonic emitter that emits sonic pulses into a solid probe. The pulses are partially transmitted and partially reflected at opposite surfaces, and the decay of the amplitude of successive sonic pulses is used to determine the acoustic impedance of the fluid.

Abstract: A method is disclosed in which an electrical conductivity of a treatment fluid is measured with one or more sensor at various instants of time. The method is further performed by generating one or more signals indicative of the electrical conductivity of the treatment fluid and transmitting the one or more signals to a computer system. The method is further performed by analyzing the one or more signals to determine a phase change in the treatment fluid based upon a positive or negative change in the electrical conductivity of the treatment fluid from a predetermined electrical conductivity range.

Abstract: An apparatus, method and system for removing fluids from a well comprising a rotary pump for positioning within the well, the rotary pump including an inlet end and a discharge end, the rotary pump comprising at least one pump impeller intermediate the inlet end and discharge end, the at least one pump impeller rotating at a rate greater than 3600 rpm; a driver for driving the at least one pump impeller to a rate greater than 3600 rpm, the driver positioned within the wellbore and operatively connected to the rotary pump; a magnetic bearing system, the magnetic bearing system operatively connected to the rotary pump and/or driver; and a digital controller positioned within the wellbore to control the magnetic bearing system. A method for removing liquids from a well and an apparatus and method for producing gas from a wellbore or injecting a fluid into a wellbore are also provided.

Abstract: An object launching apparatus for a well has a housing, a flow mandrel, and a cage. The flow mandrel is disposed in the housing's internal chamber, and a flow passage in the mandrel communicates flow from the housing's inlet to the mandrel's flow port, which in turn communicates with the housing's outlet. The cage is disposed in the internal chamber and defines pockets for holding the objects. A motor and shaft move the cage in the housing relative to the mandrel's flow port so the cage's pockets can be selectively positioned in communication between the mandrel's flow port and the housing's outlet. This allows any of the object(s) held in the positioned pocket to be launched into the flow to the well. Preferably, the motor rotates the shaft so the cage can ride linearly along the shaft's thread and the cage can rotate through a cammed engagement with the housing.

Abstract: Disclosed herein is a fixture structure for reusing an underground micro-seismic sensor, including: a sensor body configured to be inserted in a borehole and having a sensing portion for sensing micro seismic event; a first fixture portion formed at one surface of the sensor body; a second fixture portion coupled to the first fixture portion and configured to be fixed to a grouting member injected into the borehole; and a separation unit installed between the first fixture portion and the second fixture portion and configured to separate the first fixture portion and the second fixture portion from each other by external force.

Abstract: A method and system for monitoring well operations are provided. Acceleration data is generated from vibration signals collected from a well and the data is processed to indicate a well condition such as the actuation of a device and the movement and location of an actuation device.

Abstract: A downhole control device is configured to activate downhole equipment requiring control signals. The device having a housing adapted to protect electronic components; a transducer configured to measure one or more of pressure and temperature; an accelerometer; and control circuitry in communication with the transducer and the accelerometer and configured to control the operation of a downhole tool depending on data from one or more of the transducer and accelerometer. The transducer, the accelerometer and at least part of the control circuitry are mounted on a chassis that is removably inserted within the housing.

Abstract: An automated roughneck may include a backup tong and a makeup tong. The makeup tong and backup tong may be selectively movable relative to one another. The makeup tong and backup tong may include spinner and gripper assemblies respectively adapted to make up and break out threaded connections. The automated roughneck may be configurable to be removable from the drill string in a lateral direction.

Abstract: A system, apparatus, and method are provided for monitoring a subsea flow device such as a subsea flowline. The apparatus generally includes a thermoelectric device that is adapted to generate electric power from a thermal potential between the subsea flow device and the surrounding seawater. A sensor that is powered by the thermoelectric device is adapted to monitor one or more characteristics of the flow device, such as temperature or strain, and provide a radiation output that is indicative of the characteristic.

Abstract: A sensor assembly for detection of fluid flow signaling over a tubular conveyance. The assembly may be employed for activation of a variety of different downhole actuators such as firing heads for perforating guns or hydrostatic set modules for packer deployment. The assembly is configured with a flow translation device which is disposed in a manner exposed to fluid flow directed through an oilfield tubular coupled to the assembly. Thus, a detector coupled to the translation device may obtain mechanical data from the device which is reliably indicative of the flow, irrespective of the physical nature of the flow itself. As such, enhanced reliability for subsequent actuator firing based on the flow signaling may be achieved.

Abstract: An apparatus for estimating a property of a downhole fluid includes a carrier configured to be conveyed through a borehole penetrating the earth, a fluid extraction device disposed at the carrier and configured to extract a sample of the downhole fluid, and a probe cell having a window to receive the sample. The apparatus further includes a light source to illuminate the sample through the window with light photons, and a photodetector to receive light photons through the window that have interacted with the downhole fluid and generate a signal indicative of an amount of the received light photons. The generated signal is indicative of the property. The photodetector has an optical cavity having a semiconductor that has a difference between a valence energy band and a conduction energy band for electrons that is greater than the energy of each of the received light photons.

Abstract: The invention relates to a device for determining the depth and orientation of a feature in a wellbore, and to a corresponding method. It also relates to a downhole apparatus for performing an operation in a well comprising a device for determining the depth and orientation of a feature in a wellbore and a device for performing the operation. In an embodiment, a downhole device (42) for determining the depth and orientation of a feature (24, 26, 28) in a wellbore (12) containing a ferrous tubing (14) is disclosed, the device comprising: at least one magnetic field sensor (44) for monitoring the inherent magnetic field of the ferrous tubing so that the presence of the feature can be detected; and at least one orientation sensor (48) for determining the orientation of the device within the wellbore.

Abstract: A wellbore instrument system includes a pipe string extending from earth's surface to a selected depth in a wellbore. The pipe string includes at least one of an electrical conductor and an optical fiber signal channel. A power sub including an electric power source is coupled proximate a lower end of the pipe string. At least one electrically powered wireline configurable wellbore instrument is coupled to the power source in the sub.

Abstract: The invention provides a system and method for facilitating oilfield operations utilizing auditory data. In one embodiment, the present invention generates one or more auditory mapping structures whereby oilfield data may be mapped to sounds. The present invention provides at least one computer generated selection tool through which the user may select one or more portions of displayed oilfield data for auditory enhancement. Once the user has indicated an area of interest using the selection tool, the present invention may identify the oilfield data displayed within the outlined area of interest, identify auditory data associated with the displayed oilfield data utilizing one or more auditory mapping structures, and emit at least a portion of the identified auditory data to enhance the user's understanding of the displayed oilfield data.

Abstract: A downhole tractor assembly that is configured for open-hole applications. The assembly includes a force monitoring mechanism to help monitor and control forces imparted through a drive mechanism of the tractor in real time. As such, damage to open-hole formations due to excessive tractoring forces may be minimized along with mechanical damage to the tractor. Furthermore, the drive mechanism of the tractor may include multiple sondes and bowsprings with gripping saddles specially configured for contacting the well wall across a large area in a non-point and line manner so as to avoid digging into and damaging the well wall during tractoring.

Abstract: A system is disclosed that includes a tool string including one or more perforating guns, a conveyance operably coupled to the tool string at a socket coupling location and configured to help convey the tool string downhole, a load-measuring device arranged on the tool string and including one or more tension sensors configured to measure tensile load on the conveyance, the load-measuring device further including communication equipment capable of transmitting one or more uphole signals, wherein the one or more uphole signals includes measurement signals corresponding to the tensile load, and a computer system locatable at or near the surface location and communicably coupled to the tool string, the computer system being configured to receive and process the one or more uphole signals and further configured to transmit one or more downhole signals to the tool string to operate the one or more perforating guns.

Abstract: A method and system for estimating water cut or water fraction. The method may include independently establishing a production index for a region in a well. An initial flow rate in the region may be computed from the production index. Further, a measured flow rate may also be monitored within the region on an ongoing rate, for example, with a Venturi device. Thus, a comparison of the initial and measured flow rates may also take place on an ongoing basis so as to provide a real time read of fluid density. This, in turn may be used to estimate water cut of anywhere between 0 and 100% for the region in a dynamic manner. As a result, production from the overall well may be optimized with greater accuracy as a determination on the amount of production allowed, if any, is made on a region by region basis with improved water cut accuracy regarding each region.

Abstract: A shock sensing tool for use with well perforating can include a generally tubular structure which is fluid pressure balanced, at least one strain sensor which senses strain in the structure, and a pressure sensor which senses pressure external to the structure. A well system can include a perforating string including multiple perforating guns and at least one shock sensing tool, with the shock sensing tool being interconnected in the perforating string between one of the perforating guns and at least one of: a) another of the perforating guns, and b) a firing head.

Abstract: Embodiments of a bottomhole assembly BHA for completion of a wellbore are deployed on electrically-enabled coiled tubing (CT) and permit components of the BHA to be independently electrically actuated from surface for completion of multiple zones in a single trip using a single BHA having at least two electrically-actuated variable diameter packers. One or both of the packers may be actuated to expand or retract for opening and closing off a variety of flowpaths between the BHA and the wellbore, in new wellbores, old wellbores, cased wellbores, wellbores with sleeves and in openhole wellbores. Additional components in the BHA, which may also be electrically-actuated or powered, permit perforating, locating of the BHA in the wellbore such as using casing collar locators and microseismic monitoring in real time or in memory mode.

Abstract: A completion system is disclosed that includes an outer completion string having at least one sand screen arranged thereabout, one or more control lines extending externally along the outer completion string and having one or more gauges operatively coupled thereto and arranged adjacent the at least one sand screen, the one or more gauges being configured for real-time monitoring and reporting of well environment parameters, a service tool arranged within the outer completion string and having an inner tubing that defines a valve conduit, and a valve arranged within the service tool and being movable between a first position, where fracturing fluid is allowed to circulate through the at least one sand screen and the valve and into the valve conduit, and a second position, where the valve prevents the fracturing fluid from entering the valve conduit.

Abstract: Wellbore assembly for injecting fluid into a subsurface formation having multiple intervals comprising a plurality of packers having bypass channels at desired locations between the respective intervals. The assembly allows fluid to be injected down a tubing string, back up an annular region, and through the series of packers to impart incremental pressure drops along the intervals. The assembly enhances pressure support by allowing the operator to optimize wellbore injection along intervals having different formation characteristics.

Abstract: A multi-zone monitoring system allowing simultaneous measurement of separate zones of multi-zone wellbore formations comprising a multi-component umbilical containing both electrical lines and a hydraulic fluid lines, an inflatable isolation packer that can traverse through the wellbore and be inflated with hydraulic fluid to seal off a portion of the wellbore wherein the inflatable isolation packer is connected to a hydraulic line of the multi-component umbilical, wherein the inflatable isolation packer further comprises: one or more cable bypass feed throughs for the umbilical's electric and hydraulic fluid lines, wherein the hydraulic line is attached to the inflatable isolation packer with compression fittings.

Abstract: A logging tool or logging tool sub (10) for downhole use comprises an elongate cylindrical body (11) having supported thereby one or more movable landing extensions(12) that are movable between an extended position in which part of each said movable landing extension protrudes beyond the exterior of the cylindrical body (11) so as to define one or more exposed landing surfaces that are engageable with one or more landing surfaces (21) of a further component; and a retracted position in which each said movable landing extension (12) protrudes externally of the cylindrical body no further than the exterior thereof (11).

Abstract: A method of recovering heat from hot produced fluids at SAGD facilities is described that utilizes wellpad steam generation such as Direct Steam Generators (DSG). Heated fluids produced by SAGD are used to preheat the water that is used to make steam for SAGD. Feedwater is conveniently preheated at the wellpads by the produced fluids, emulsions, and/or gases before feeding to the DSGs.

Abstract: A downhole measurement apparatus includes a tool body supporting a logging tool. The logging tool includes a detector outsert coupled into and exposed through an exterior pocket of the tool body to position the outer surface of the outsert adjacent or in close proximity to the outer diameter of the tool body. A stabilizer or off-center stabilizer may be provided to further deflect the outsert portion of the logging tool toward an earth formation to increase detector proximity to the formation. Radial and axial distances can be calibrated and maintained across multiple different tool collars.

Abstract: A method and apparatus for preventing erosion of a cable for use in a wellbore is described herein. The cable has one or more optical fibers adapted to monitor and/or control a condition in the wellbore. The cable includes a layer of elastomeric material at least partially located on an outer surface of the cable. The elastomeric material is adapted to absorb energy due to the impact of particles in production fluid or wellbore fluid against the cable.

Abstract: Apparatus including a sensor-containing body is disposable within a flowbore of a downhole tool. The apparatus also comprises an adjustable engagement mechanism that is coupled to the body. The engagement mechanism has a first position that allows the body to move longitudinally through the flowbore, and a second position that prevents movement of the body relative to the flowbore.

Abstract: A packer deployed well wall monitoring or transceiver assembly. The assembly may be particularly suited for use with swellable packers wherein the sensor or transceiver is delivered in a manner that substantially avoids damage thereto. Furthermore, the pre-deployment configuration of the assembly may enhance the deployment and reliability of the sensor in terms of formation monitoring over time. The deployment of the packer provides the energy required for the sensor or transceiver to contact the well wall. The packer elastomeric material provides or can be enhanced to provide isolation of the sensor or transceivers from extraneous borehole disturbances improving their signal to noise characteristics.

Abstract: A method for securing a signal propagating line to a downhole component includes configuring the downhole component in a final form prior to securing the line thereto; positioning the line at an outside dimension of the component; and fusing the line to the component with a heat based fusion method and apparatus therefore.

Abstract: The present disclosure relates to a flow meter for measuring multi-phase flow and method of use. The flow meter comprises an impeller assembly having a one or more blades in an asymmetric blade configuration and one or more sensors to measure partial rotations of the blades. With this local velocity information, the operation of a system may be enhanced.

Abstract: The present disclosure is directed at a method and system for determining relative depth of an acoustic event within a wellbore. The method includes obtaining two acoustic signals at two different and known depths in the wellbore, in which each of the acoustic signals includes the acoustic event; dividing each of the acoustic signals into windows; determining cross-correlations of pairs of the windows, in which each of the pairs includes one window from one of the acoustic signals and another window from the other of the acoustic signals that at least partially overlap each other in time; and determining the relative depth of the acoustic event relative to the two known depths from the cross-correlations. The acoustic event may represent, for example, fluid flowing from formation into the wellbore (or vice-versa) or fluid flowing across any casing or tubing located within the wellbore.

Abstract: An apparatus for communicating electrical power and data between downhole devices. The apparatus includes a wellbore tubular having a wall. An electrical device is positioned in a wellbore region to an exterior of the wellbore tubular. A first acoustic coupling element is positioned to the exterior of the wellbore tubular and is electrically connected to the electrical device. A second acoustic coupling element is positioned to an interior of the wellbore tubular. The second acoustic coupling element is operable to transmit electrical power to and receive data from the first acoustic coupling element through communication of acoustic signals through the wall of the wellbore tubular.

Abstract: An apparatus includes a radiation source to output radiation after power is supplied. The apparatus also includes a power source to supply power. The apparatus includes an ambient-activated switch electrically coupled between the radiation source and the power source. The ambient-activated switch is to switch to an open position while a value for an ambient characteristic for the ambient-activated switch is at an ambient level for a surface of the Earth. The ambient-activated switch is to switch to a closed position while the value for the ambient characteristic for the ambient-activated switch is at a downhole ambient level, wherein the ambient-activated switch is to electrically couple the power source to the radiation source while in the closed position.

Abstract: A method of activating a tool can include displacing a device in the tool, the device transmitting energy to a receiver of the tool, thereby activating the tool, and the transmitting including a control circuitry increasing electrical current flow between an electrical power source and a transmitter in response to a sensor detecting a predetermined stimulus downhole. A system can include a tool including a receiver and an electrical load, and a device which displaces relative to the tool, the device including a transmitter, a sensor and an electrical power source. Another method can include displacing a device in a tubular string including multiple downhole tools, each including a receiver and an electrical load, and the device including a transmitter and a sensor. The transmitter transmits energy to at least one of the receivers in response to sensor detection of a predetermined number of the tools traversed by the device.

Abstract: A production logging tool (PLT) is conveyed within production tubing containing production fluid flow established by zonal fluid flow from formation zones. The PLT measures a flow rate of the production fluid flow at each of a plurality of depths associated with a corresponding one of the zones. A flow rate of the zonal fluid flow from each zone is determined based on the flow rates of the production fluid flow measured at each of the depths. The PLT measures proportions of compositional components of the production fluid flow at each of the depths. A flow rate of each compositional component of the zonal fluid flow from each zone is determined based on the determined flow rate of the zonal fluid flow from each zone and the proportions of compositional components of the production fluid flow measured at each of the depths.

Abstract: An opto-acoustic subsystem is provided. The subsystem includes an optical transmitter and an actuator device. The optical transmitter can be positioned at a surface of a wellbore. The actuator device can be positioned in the wellbore and can respond to a modulated electrical signal generated from a modulated optical signal received from the optical transmitter by outputting a modulated acoustical signal into an environment of the wellbore.

Abstract: Disclosed are systems and methods for carrying out multiple-interval stimulation of a wellbore. One disclosed method includes introducing one or more wellbore projectiles into a work string including a completion assembly having a first downhole tool arranged within a first interval, a second downhole tool arranged within a second interval, and a third downhole tool arranged within a third interval that interposes the first and second intervals, detecting the one or more wellbore projectiles with first and second sensors of the first and second downhole tools, opening first and second sliding sleeves arranged within the first and second downhole tools, treating the first and second intervals, sealing the first and second intervals, detecting a wellbore projectile with a third sensor of the third downhole tool, opening a third sliding sleeve arranged within the third downhole tool, and treating the third interval independent of the first and second intervals.

Abstract: Electrically conductive proppants and methods for detecting, locating, and characterizing same are provided. The electrically conductive proppant can include a substantially uniform coating of an electrically conductive material having a thickness of at least 500 nm. The method can include injecting a hydraulic fluid into a wellbore extending into a subterranean formation at a rate and pressure sufficient to open a fracture therein, injecting into the fracture a fluid containing the electrically conductive proppant, electrically energizing the earth at or near the fracture, and measuring three dimensional (x, y, and z) components of electric and magnetic field responses at a surface of the earth or in an adjacent wellbore.