Abstract: Fiber optic sensors are described for detecting the operational position of a downhole moveable device. In one example, an electric or magnetic field is emitted into the wellbore and interacts with the moveable assembly, thereby producing a secondary electric or magnetic field. The secondary field is detected by a fiber optic sensor which produces a corresponding response signal. The response signal is then processed in a variety of ways to determine the operational position of the moveable device. In another example, the operational position is determined using fiber optic temperature or acoustic sensors. A temperature or acoustic vibration reading is acquired before and after actuation of the moveable device. The two readings are then compared to determine the operation position of the moveable device.

Abstract: Techniques for plugging at least one zone of a hydrocarbon well are disclosed herein. The techniques include methods for deploying a wellbore dart configured for plugging the at least one zone of the hydrocarbon well, receiving, by a first node, location information indicating a first location of the wellbore dart, receiving, by a second node, location information indicating a second location of the wellbore dart, and detecting, an arrival of the wellbore dart at an intended location for the dart to plug the zone of the hydrocarbon well. In some aspects, the method further includes sending a command to a firing module of the wellbore dart, the command effective to cause the wellbore dart to plug the zone of the hydrocarbon well. Systems and computer-readable media are also provided.

Abstract: A disclosed control system for a gas assisted plunger lift (GAPL) system includes a sensor and a processor circuit. The sensor is configured to measure a plunger speed and/or velocity and the processor circuit is configured to control various parameters of the GAPL based on the measured plunger speed and/or velocity. The processor circuit may be configured to adjust a gas injection rate parameter based on the measured plunger speed and/or velocity, and/or may adjust one or more parameters including: a close time, an afterflow time, a flow rate, a load factor, a tubing pressure, a casing pressure, and a tubing/casing differential pressure. The controller may be further configured to adjust all parameters simultaneously or may sequentially adjust a first sub-set of parameters and then adjust a second sub-set of parameters. The first sub-set may include a gas injection flow rate and the second sub-set may include after-flow and close time parameters.

Abstract: A Programmable plug system for accessing and isolating formations during hydraulic fracturing, consisting of a Programmable Plug and plurality of Sliding Sleeve Valves installed in the casing string of a wellbore, wherein Programmable Plug travels, downwards or upwards through the casing and Sliding Sleeve Valves, wherein during its travel the Programmable Plug detects and counts each sleeve using on-board sensors, electronics and software and wherein the Programmable Plug utilizes detected information to locate, activate and engage itself into the Sliding Sleeve Valves, one at a time, from the top or from the bottom, without locking in, according to programmed sequence (to open, close or bypass) stored in the on-board memory.

Abstract: An asset identification system includes a tool having an axial dimension and a radial dimension. There are three RFID devices located on the tool, and the three RFID devices are located at equal angles with respect to each other in the radial dimension. The system further includes a storage apparatus configured to store the tool, and an RFID reader. At least one of the three RFID devices located on the tool is readable by the RFID reader regardless of the radial orientation of the tool with respect to the RFID reader.

Abstract: A method for locating a casing collar in a well is disclosed. The method includes lowering an accelerometer into the well to slide along a casing wall of the well, generating a data log by measuring an accelerometer signal from the accelerometer as the accelerometer slides along the casing wall, analyzing, by a computer processor, the data log with respect to a predetermined data feature to detect an accelerometer signal event, and determining, by the computer processor and based on the accelerometer signal event, a location of the casing collar in the well.

Abstract: An inflow control device (“ICD”) is in production tubing in a wellbore, and used to control a flow of fluid through the ICD. The ICD is adjustable in response to an external force, which is selectively applied by an actuator that is included with a bottom-home assembly (“BHA”). The BHA is deployed on coiled tubing, and anchored in the wellbore to isolate the coiled tubing from resultant or counter forces generated when adjusting the ICD. Fluid is optionally injected into the coiled tubing on surface, and directed into the wellbore from the BHA. A latching arm is included with the actuator, which is equipped with a profile that matches a profile on the ICD to facilitate engagement between the arm and the ICD.

Abstract: A method and system for a perforating gun having a box by pin perforating gun system using swaged down gun bodies. The box by pin perforating gun system may include a removable cartridge to hold a detonator with a switch and an insulated charge holder as an electrical feed-through.

Abstract: Methods and systems are provided for controlling a robot to navigate a perceptually aliased environment, the robot being configured to infer a first Gaussian mixture model (GMM) of a first pose of the robot, and to plan an optimal control action by: determining a second GMM of a simulated pose of the robot by simulating applying the first control action to the first GMM; determining from the second GMM a range of possible observations; calculating scene probabilities for associating each possible observation with each aliased scene of a set of aliased scenes; calculating from the scene probabilities an objective function to determine an estimated cost of the first control action; and comparing the estimated cost of the first control action with estimated costs calculated for one or more additional control actions, to determine an optimal control action.

Abstract: Systems and methods are disclosed for a well tool. The well tool system includes a receiving tool disposed in a wellbore tubular. The receiving tool is configured to transition from an inactive state to an active state in response to a triggering signal. The well tool system further includes a transmitting tool at a surface and proximate to the receiving tool. The transmitting tool is configured to wirelessly transmit the triggering signal to the receiving tool.

Abstract: A method for monitoring well operations comprises sensing oscillations occurring in the well during a well operation and generating a signal indicative of the oscillations. The signal is processed into sensed data indicative of the oscillations sensed in the well, and the sensed data is then compared with reference data associated with previously detected well operations, to identify the well operation that generated the sensed oscillations. The system that performs the well monitoring, comprises one or more transducers configured to sense the oscillations, and a processing system in communication with the transducer which identifies the well operation and the device that caused the oscillations, based on comparisons of data indicative of the oscillations, with reference data associated with previously detected well operations.

Abstract: A casing deployment apparatus includes a processing resource with a signal pattern recognition engine unit (420), a tubular measurement unit (404) and a decision unit (416). A first sensor input (402) and a second sensor input (406) are attached to the pattern recognition unit (420) and receive first sensor data and second sensor data corresponding to first and second time-varying sensor signals. The pattern recognition unit (420) analyzes a characteristic of the first sensor data to determine whether the characteristic is substantially consistent with a first expected characteristic of the first sensor data associated with deployment of casing in a borehole. The tubular measurement unit (404) analyzes a characteristic of the second sensor data in order to determine whether the characteristic is substantially consistent with a second expected characteristic of the second sensor data associated with the deployment of the casing.

Abstract: Systems and methods for signaling the detection of a fluid change in a wellbore can be used during wellbore operations, such as cementing a casing in the wellbore. The systems and methods involve using burst discs to provide a pressure pulse that can be detected uphole and there by provide a signal related to when a fluid change has reached a predetermined position in the wellbore. The burst discs can be activated to prevent fluid flow in a portion of the wellbore by a sensor that detects a property that is different between two fluids. Once activated, the pressure of the fluid on the burst discs subsequently ruptures the burst disc and creates the pressure pulse.

Abstract: A method of cross-tool optical fluid model validation includes selecting verified field data measured with a first sensor of an existing tool as validation fluids and selecting a second sensor for a new tool or on a different existing tool. The method may also include applying cross-tool optical data transformation to the validation fluids in a tool parameter space from the first sensor to the second sensor, and calculating the synthetic optical responses of the second sensor on the validation fluids through cross-space data transformation. The method may further include determining a new or adjusting an existing operational fluid model of the second sensor in a synthetic parameter space according to the candidate model performance evaluated on the validation fluids, and optimizing well testing and sampling operation based on real-time estimated formation fluid characteristics using the validated fluid models of the second sensor in an operating tool.

Abstract: A pump monitoring system is provided, the pump including a rotor, and stator, the system including a magnetic field sensor to measure a magnetic field generated by a magnet positioned on a rod above the rotor; and a computer system configured to use the magnetic field to determine the rotor position. The magnetic field generated by the magnet can be used to determine characteristics of the pump including slipping and sticking, twist and twist differential, togging and wobble.

Abstract: A system that provides for the measurement and control of proppant concentration in a liquefied gas fluid stream utilizing a non-nuclear optical detection device such as a near-infrared (NIR), visible (Vis), and ultraviolet (UV) photometer/nephelometer to be used in the fracture treatment of subterranean hydrocarbon formations.

Abstract: A system for determining a location and a diameter of a pipe deployed in a bore includes a plurality of circumferentially spaced acoustic transmitters and a plurality of circumferentially spaced acoustic receivers deployed in a wall of the bore. A processor is configured to identify and process received acoustic waveforms that are reflected by the pipe to compute the location and the diameter of the pipe. The system may include a drill string deployed in a drilling riser.

Abstract: An example method for downhole operations using a magnetic monopole includes positioning at least one of a transmitter and a receiver within a first borehole. At least one of the transmitter and the receiver may be a magnetic monopole. The transmitter may generate a first magnetic field, and the receiver may measure a signal corresponding to the first magnetic field. A control unit communicably coupled to the receiver may determine at least one characteristic using the received signal.

Abstract: A drilling equipment tracking system includes a piece of drilling equipment and a traceability tag coupled to the piece of drilling equipment. The traceability tag has a unique identifier. A mobile device is configured to obtain the unique identifier and access a remote server containing an equipment file corresponding to the piece of drilling equipment based on the unique identifier.

Abstract: A sleeve actuation method for actuating sleeves in a reverse direction. The method includes a use of stored energy created by injecting into a connected region of a well such that the stored energy is used to actuate a tool installed in a wellbore casing that is either heel ward or uphole of the connected region. The tool actuated in a direction from toe end to heel end while the tool reconfigures to create a seat for seating plugging elements.

Abstract: A system for determining a location of a drill pipe joint deployed in a bore includes at least one magnetometer deployed on the bore. A processor is in electronic communication with the magnetometer and is configured to process magnetic field measurements made by the magnetometer to determine at least one of an axial position and a lateral position of the drill pipe joint.

Abstract: Electrically-operated downhole tools are run into a wellbore on a coiled tubing string which includes tube-wire that is capable of carrying power and data along its length. During operation, a downhole tool is provided power from surface using the tube-wire. Downhole data is provided to the surface via tube-wire.

Abstract: The present invention generally concerns the treatment of hydrocarbon-bearing formations adjacent a wellbore. In one embodiment, fracturing jobs are performed through the use of subs disposed in a casing string having profiles that interact with profiles formed on retractable keys of a tool.

Abstract: An apparatus, method and computer-readable medium for locating a joint of a casing disposed in a borehole are disclosed. The apparatus includes a sensor oriented in a plane orthogonal to a longitudinal axis of the casing. The sensor measures a magnetic field induced in the casing by the earth's magnetic field. A tool conveys the sensor through the casing along a path that is radially offset from a longitudinal axis of the casing. Transverse magnetic field measurements are obtained by the sensor at a plurality of depths along the casing. A change in the transverse measurements is identified and used to determine the location of the casing joint.

Abstract: A system and method for monitoring a wellbore are disclosed herein. A pulse generator comprises a plurality of ports, wherein a first one of the plurality of ports is coupled to a first location of interest and a second one of the plurality of ports is coupled to a second location of interest. An electromagnetic pulse is generated at the first port and the second port. A reflected electromagnetic pulse is received at the first port and the second port. In another embodiment, the pulses are received at a separate pulse receiver with a plurality of receiving ports. A data storage device is coupled to the pulse generator or the pulse receiver, and data relating to the reflected magnetic pulse is stored at the data storage device.

Abstract: A method of freeing a pipe stuck in a subterranean well can include determining a location of a portion of the pipe stuck in the well, and penetrating and/or heating a sidewall of the pipe portion with a beam of light. A system for freeing a pipe stuck in a subterranean well can include a tool deployed into a portion of the pipe stuck in the well by a differential pressure from a wellbore to a formation penetrated by the wellbore. A beam of light emitted from the tool penetrates the pipe portion. Another method of freeing a pipe stuck in a subterranean well can include determining a location of a portion of the pipe which is biased against a wall of a wellbore by differential pressure, and directing a beam of light to the pipe portion.

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: Systems and methods for use in wellbore completion and/or for operating a downhole tool, such as a downhole tool associated with well fracturing, include a tool assembly having a lower packer, an upper packer, a first downhole tool in the form of a flow control device, a second downhole tool in the form of a fracture tool, a plurality of production tools and a plurality of screens. Each tool assembly includes or is associated with a downhole actuator in the form of a shifting tool which is operable to actuate one or more of the first downhole tool, second downhole tool or production tools in use. The actuator may be disposed on, or operatively associated with a string, such as a tubular string. All operations are performed with a body of the shifting tool in tension.

Abstract: A method is for determining the position of a lower portion of a drill string in a bore hole. The drill string comprises a number of drill string components, each drill string component being interconnected by means of at least one joint. Several ultrasonic sensors are arranged after each other along a drill string. The method comprises localizing the position of the chamfer of the joint relative to the ultrasonic sensors.

Abstract: A method includes accepting as input to a processor measurements of a characteristic of a subsurface formation made at a plurality of spaced apart positions along a pipe string moved along a wellbore. Measurements are made of pipe string depth in the wellbore from the Earth's surface. The measurements of pipe string depth include measurements of apparent depth of each of the spaced apart locations. The subsurface formation is identified from the measurements of the characteristic. A true depth of the subsurface formation is made using the measurements of pipe string depth and apparent depth of the formation from each of the spaced apart positions. A record of measurements of the characteristic with respect to depth corrected for changes in length of the pipe string caused by axial forces along the pipe string is generated.

Abstract: A system for fracturing a subterranean formation includes a housing having one or more radially directed ports therein. A valve disposed within the housing proximate the one or more ports. A seat member interactive with the valve to rapidly prevent or substantially retard fluid flow therethrough. A method for initiating a fracture in a subterranean formation is included.

Abstract: A data logging apparatus for use in a wellbore of a fluid production well includes a forward portion for guiding the data logging tool through the wellbore. An elongated body having a first end and a second end includes electronic circuitry for receiving data from at least one sensor provided on the data logging tool. An elongated shaft having a first end is connected to the forward portion, and a second end of the elongated shaft is connected to the first end of the elongated body. A propulsion assembly is connected to the second end of the elongated body for self-propelling the data logging tool through the fluid production well. The self-propelled data logging tool can transverse though the wellbore having inclinations of at least fifty degrees. An outwardly extending support arm assembly is rotatably attached about the elongated shaft to prevent the logging tool from uncontrollably spinning.

Abstract: Continuous measurement indicia between casing collars of a pipe segment of a well bore casing is obtained from signals obtained by sensing innate, persistent and unaltered characteristics, e.g. magnetic permeability, of the pipe segment along its length, and using the signals to perform a downhole function, e.g. a gravity measurement, at an indicated location.

Abstract: A system to detect a position of a pipe with respect to a BOP includes a casing disposed around an outer surface of a section of the pipe. The system further includes sensing devices that are disposed on the casing and arranged to form a plurality of arrays and configured to generate position signals. The arrays are disposed circumferentially around the casing and spaced from one another along the length of the casing. The system includes a processing unit configured to compute distance between the pipe and each sensing device. The processing unit generates a first alert when the distance between the pipe and at least one sensing device is different from a reference distance. The processing unit generates a second alert when the distance between the pipe and each sensing device of at least one array of sensing devices is different from the reference distance.

Abstract: A weight down tool comprises a central mandrel configured to be coupled to a wellbore tubular, an outwardly extending indicator disposed about the central mandrel, and a plurality of radially expandable weight down lugs configured to engage a lower restriction and prevent downwards movement of the central mandrel with respect to the lower restriction when disposed in an expanded position. The indicator is configured to retract inwards in response to moving through an upper restriction in a downwards direction to expand the weight down lugs into the expanded position in response to moving through the lower restriction in an upwards direction. The weight down lugs are configured to retract out of the expanded position in response to moving through the upper restriction in an upwards direction.

Abstract: An ultrasonic position sensing system is disclosed. In one embodiment, the system includes an ultrasonic sensor configured to monitor the position of a device. The system also includes ranging logic. The sensor is controlled by the logic to direct an ultrasonic pulse toward the device. The logic is configured to compute the transit time and the velocity of the ultrasonic pulse. Based on these parameters, the logic computes the path length between the sensor and the device, which corresponds to the location of the device relative to the location of the sensor. In further embodiments, the ultrasonic positioning system may include multiple sensors in communication with the ranging logic for monitoring multiple devices.

Abstract: A method of operating an isolation valve in a wellbore includes: deploying a work string into the wellbore through a tubular string disposed in the wellbore. The work string comprises a deployment string, a shifting tool, and a bottomhole assembly (BHA). The tubular string comprises the isolation valve and an actuator. The method further includes rotating the actuator using the shifting tool, thereby opening or closing the isolation valve. The isolation valve isolates a formation from an upper portion of the wellbore in the closed position.

Abstract: A wellbore fluid treatment assembly includes: a tubing string, a fluid port extending through the tubing string wall, the fluid port positioned in a shift gap created by movement of a sliding sleeve valve when opening the fluid port; and a tool for locating the fluid port in the tubing string, the tool including: a body, a locking protrusion encircling a circumference of the body, at least a portion of the locking protrusion having a length measured along the tool's long axis selected to fit into the shift gap.

Abstract: The present invention generally relates to an apparatus and a method of transmitting data from a rotating control device. In one aspect, a method of transmitting data from a rotating control device coupled to an offshore drilling unit is provided. The method includes the step of generating data relating to a parameter associated with the rotating control device. The method further includes the step of transmitting the data from a transmitting assembly coupled to the rotating control device to a receiving assembly positioned proximate the transmitting assembly. Additionally, the method includes the step of transmitting the data from the receiving assembly to the offshore drilling unit. In another aspect, a data gathering and transmitting system for use with a rotating control device coupled to an offshore drilling unit is provided. In a further aspect, a method for transmitting data generated in a rotating control device coupled to a riser is provided.

Abstract: A sensing indicator for a downhole tool, the sensing indicator includes a sensing mechanism including a sensing device and an RFID tag. Wherein the RFID tag is only readable when a set limit is exceeded. The set limit related to a sensed condition of a downhole component of the downhole tool; and, a housing supporting the sensing mechanism. The housing protecting the sensing mechanism from downhole conditions.

Abstract: A system and method is disclosed for utilizing a radio frequency communication system to wirelessly exchange data with well logging tools and external devices. A logging tool component is operably fitted with an extension antenna which travels through the thick casing of the logging tool. The extension antenna enables data exchange, for example, between radio frequency identification tags inside the logging tool and devices outside of the logging tool.

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

Abstract: A 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 hang-off tool for supporting a tool inside a tubular member includes a logging string configured to generate logging data, a computing system coupled to the logging string and configured to communicate the logging data to another tool, and a radially expandable member having a retracted position and an expanded position. The radially expandable member is configured to engage a radially-increased profile of an inner surface of the tubular member in the expanded position to support the hang-off tool. The radially expandable member is also configured not to engage the radially-increased profile in the retracted position.

Abstract: A system for detecting when a plunger reaches a bottom of a well includes a pressure sensor configured to measure a pressure of the well and provide a measured pressure output. Derivative calculation circuitry calculates a derivative of the measured pressure output. Detection circuitry detects when the plunger reaches the bottom of the well based upon the calculated derivative.

Abstract: Provided are a system and method for identifying planned markers while drilling a borehole. In one example, the method includes obtaining a plan containing planned markers that each corresponds to a baseline marker from an existing well. Each of the baseline markers corresponds to a waveform from a log file obtained from the existing well and is associated with a waveform representation of the corresponding waveform. Each of the planned markers is associated with an estimated true vertical depth (TVD) value. A second log file corresponding to the borehole is obtained that contains waveforms representing formation information detected within the borehole. The second log file is scanned for a planned marker based on the estimated TVD value and the waveform representation of the baseline marker corresponding to the planned marker. At least one match may be identified and reported for the planned marker.

Abstract: Wireless downhole sensor technology is being deployed in oil and gas wells. System components are inductively coupled, which enables remote placement of apparatus on the outside of wellbore conduit without the need for any wired connection. These systems make use of a pair of conductive elements that need to be aligned in the well. Embodiments of the present invention provide techniques to correctly space out the wellbore completion string so that the down-hole conductive elements will be properly aligned and within proximity to establish wireless connectivity, as the wellbore completion string is set and the tubing hanger is landed inside the wellhead housing of the well.

Abstract: A technique that is usable with a well includes communicating a stabilized treatment slurry downhole into the well and dehydrating a portion of the slurry to form a barrier in the well.

Abstract: A system of couplings and method of use of the couplings to locate a downhole tool connected to coiled tubing, such as a bottom hole assembly, within a selected segment of a casing string. The selected segment of casing may be a ported collar or ported housing that permits the treatment and/or stimulation of the adjacent well formation. The system of couplings may be two, three, or four couplings spaced apart at predetermined lengths. The predetermined lengths may be shorter than typical lengths of casing segments. The distance between the first and second coupling may be substantially identical to the distance between the third and fourth coupling. The use of distances between the couplings that are shorter than the length of conventional casing segments may provide surface indicators as to the location of the bottom hole assembly with a higher confidence than relying on a traditional tally sheet.

Abstract: A downhole apparatus including a tool body and a sealing element disposed within the tool body. Also, at least one sensor disposed on the tool body, wherein the sensor is configured to take measurements from a well and wherein the sensor measures an actuation condition, the sensor signals the sealing element to actuate. Also, a method of sealing a portion of a well including disposing an automatic packer in a well, wherein the automatic packer includes a tool body, a sealing element disposed within the tool body, and a sensor disposed on the tool body. The method also includes measuring a condition within the well, determining an actuation condition with the sensor, and expanding the sealing element into contact with an inner diameter of the well when the actuation condition is determined.