Abstract: Systems and methods for monitoring, diagnosing and optimizing operation of a gas lift (GL) system, at least some of which include a method that includes collecting measured data representative of the GL system's state, storing the measured data, comparing the measured data to a well model's calculated data for the well and identifying likely conditions of the GL system based on mismatches between the measured data and the calculated data. The method further includes updating the model to reflect the likely conditions and selected corrections of the likely conditions, generating GL system performance curves using the updated model and presenting to a user actions recommended to achieve a GL system performance consistent with a GL system operating point on at least one of the GL system performance curves.

Abstract: A system for deploying and powering an electric submersible pump within a subterranean well. The system includes a tubing string having a wall forming a hollow interior, one end of the tubing string connected to the electric submersible pump; a flowable conductive material at least partially filling the hollow interior of the tubing string, the flowable conductive material forming a first conductive path; and a second conductive path, wherein the first conductive path and the second conductive path form a circuit for supplying power to the electric submersible pump. A method for deploying and powering an electric submersible pump within a subterranean well is also provided.

Abstract: An integrated and rigless method of determining the location and the type of damage in casing or tubing of a wellbore that involves recording a thickness profile of the casing or tubing, a temperature log, and a noise log along the depth of the wellbore, followed by locating the damage from the thickness profile, and determining the type of damage from the temperature log and the noise log.

Abstract: Various embodiments include apparatus and methods to generate geosignal responses. Geosignal responses may be generated that include a representation of a determination of variation between a XX coupling component and a YY coupling component from acquired signals. Such geosignals may be used to 5 address a blindspot problem suffered in conventional geosteering in a drilling condition where the logging tool is located at layered formations with symmetric resistivity profiles. Additional apparatus, systems, and methods are disclosed.

Abstract: A fluid sensor cable assembly and method uses one or more conductive bodies extending along an elongated core body for conducting a heating current to heat the cable assembly. The one or more conductive bodies also are configured to conduct an interrogation signal and to conduct reflections of the interrogation signal. One or more optical fibers extend along the length of the core body and include temperature sensitive elements at different locations along the length of the core body. The temperature sensitive elements measure heat flux out of the cable assembly at the different locations subsequent to heating the cable assembly and communicate the heat flux to a computer acquisition system.

Abstract: A method of determining a concentration of hydrogen sulfide in a fluid comprises exposing a sensor to the fluid, the sensor comprising a pair of electrodes defining a gap therebetween and a sensing material bridging the gap between the electrodes, measuring a value of an electrical parameter of the sensor at an applied frequency of greater than about 10 kHz and a voltage of less than about 1.0 volt when the sensor is exposed to the fluid, and determining the concentration of hydrogen sulfide in the fluid based at least in part on the measured value of the electrical parameter. Related apparatuses and methods are also disclosed.

Abstract: A well integrity monitoring system may include one or more sensing elements that are configured to generate feedback indicative of an integrity of a well. The one or more sensing elements may be disposed in at least one annulus of wellhead assembly. Additionally, the well integrity monitoring system may include a controller coupled to the wellhead assembly. The controller may be configured to wirelessly determine the feedback from the one or more sensing elements.

Abstract: Electrically conductive proppant particles having non-uniform electrically conductive coatings are disclosed. The non-uniform electrically conductive coatings can have a thickness of at least about 10 nm formed on an outer surface of a sintered, substantially round and spherical particle, wherein less than 95% of the outer surface of the sintered, substantially round and spherical particle is coated with the electrically conductive material. Methods for making and using such electrically conductive proppant particles having non-uniform electrically conductive coatings are also disclosed.

Abstract: Wellbore treatment compositions comprising non-radioactive tracer materials and methods for using the non-radioactive tracer materials to determine the location of treatment fluids within a subterranean formation are provided herein. A method comprising introducing a treatment fluid comprising a non-radioactive tracer material into a subterranean formation; exposing a portion of the subterranean formation to neutrons from a neutron source to activate the non-radioactive tracer material in the portion of the subterranean formation; and detecting gamma rays emitted by the activated tracer material in the portion of the subterranean formation.

Abstract: Systems and methods for communicating information relating to at least one wellbore condition across a surface cement plug in a plugged off wellbore. Induction telemetry or galvanic telemetry are used to transmit electromagnetic signals across the axial length of a surface cement plug.

Abstract: A wireless actuation system comprises a transmitter, an actuation system comprising a receiving antenna, and one or more sliding members transitional from a first position to a second position. The transmitter is configured to transmit an electromagnetic signal, and the sliding member prevents a route of fluid communication via one or more ports of a housing when the sliding member is in the first position. The sliding member allows fluid communication via the one or more ports of the housing when the sliding member is in the second position, and the actuation system is configured to allow the sliding member to transition from the first position to the second position in response to recognition of the electromagnetic signal by the receiving antenna.

Abstract: A downhole assembly includes an isolation tool disposable downhole of a perforation gun. The isolation tool includes a tubular body having a seat, and an occluding device supported on the tubular body in an unseated position, and movable to a seated position on the seat in response to at least one of a firing operation of the perforation gun and a selected fluid velocity through the isolation tool. Fluid communication through the isolation tool is allowed in uphole and downhole directions in the unseated position of the occluding device, and blocked in the downhole direction in the seated position of the occluding device.

Abstract: Various implementations directed to determining a phase behavior of a reservoir fluid are provided. In one implementation, a method may include receiving a plurality of predetermined pore size data, a plurality of predetermined bulk fluid data, and a plurality of predetermined kerogen data that are based on historical data for a plurality of hydrocarbon reservoirs. The method may also include creating a library of a plurality of simulated phase behavior data for the predetermined pore size data, the predetermined bulk fluid data, and the predetermined kerogen data. The method may further include determining a phase behavior of a reservoir fluid disposed in an actual hydrocarbon reservoir using the library.

Abstract: A system includes a downhole rotary separator located within the well formation and configured to generate a hydrocarbon rich stream and a first water stream from a well fluid obtained from a production zone. The system also includes an electrical submersible pump disposed within the well formation and operatively coupled to the downhole rotary separator, wherein the electrical submersible pump is configured to transfer the hydrocarbon rich stream to a surface of the earth. The system further includes a surface separator located on the surface of earth and operatively coupled to generate oil and a second water stream from the hydrocarbon rich stream. The system also includes a hydraulic motor disposed within the well formation and operatively coupled to the downhole rotary separator, wherein the hydraulic motor is configured to drive the downhole rotary separator using a drive fluid comprising the hydrocarbon rich stream or the second water stream.

Abstract: The monitoring and control system is configured to obtain a hook load data at predetermined time intervals, and determine variation of hook load between the predetermined time intervals using the hook load data obtained. The monitoring and control system further determines a slip status of a drill string corresponding to each of the variation of hook load. The slip status is determined by comparing each of the variation of hook load with a threshold value of noise. The threshold value of noise is determined based on predetermined parameters of the drill string. The slip status of the drill string corresponding to each of the variation of hook load may be verified based on one or more predetermined conditions. The slip status of the drill string corresponding to each of the variation of hook load may be corrected by adjusting predetermined parameters, based on verification of one or more predetermined conditions.

Abstract: A method and apparatus for collection and analysis of oil rig activity is described. The method includes collecting wellsite data from a plurality of sources, including real-time data sources and macroscopic reports. In certain embodiments, the collected data may be standardized based on templates specifying data format and presentation. Additionally, the data may be automatically corrected by using data error lists that identify algorithms for diagnosing and correcting errors in the data. Data collected from multiple sources may be time-aligned so that data from different sources may be correlated together by time. In certain embodiments, time aligning the data may include adjusting manually-logged timestamps for events in macroscopic reports based on real-time data. In this way, heterogeneous data from a plurality of sources may be homogenized. Optionally, the homogenized data may be used as inputs for wellsite data analysis or to produce various types of quality reports.

Abstract: Provided herein are methods and apparatus for collecting and preserving core samples from a reservoir. In some embodiments, a method includes obtaining core samples from a reservoir using a rock and fluid sampling tool and depositing the core samples in a vessel filled with a hydrogen-free fluid such that a portion of the hydrogen-free fluid is displaced by the core samples and the core samples are immersed in the hydrogen-free fluid. The method also includes transferring a gas into the vessel to occupy a space in the vessel and sealing the vessel via a cap on an end of the vessel. Methods of analyzing the core samples core samples collected from a reservoir and a rock and fluid sampling tool are also provided.

Abstract: Fluid densities can be monitored in real-time in a wellbore, such as during downhole stimulation operations, using an acoustic pressure-sensing system. The measured acoustic signal can be used to determine pressure fluctuations of a fluid in non-laminar flow. An estimated density of the fluid can be calculated based on the pressure fluctuations of the fluid and a known flow rate of the fluid. The flow rate of the fluid can be known, such as when being held constant by surface equipment or when measured at the surface.

Abstract: An apparatus for communicating optical signals between an external device located on a first side of a wellbore barrier and a downhole device located on a second side of the well bore barrier includes a first wireless node which is positioned on the first side of the well bore barrier and is in communication with the external device via a first cable. A second wireless node is positioned on the second side of the well bore barrier and is in communication with the downhole device via a second cable. The first and second wireless nodes are configured to communicate wirelessly through the well bore barrier using near field magnetic induction (NFMI) communications.

Abstract: A logging apparatus for use in a well can include at least one sensor that senses a well parameter, at least one buoyancy control device, and the logging apparatus extending helically between opposite ends of the logging apparatus. A method of logging in a subterranean well can include installing at least one logging apparatus in the well, and the logging apparatus helically displacing in the well as a sensor of the logging apparatus senses a well parameter. A well system can include at least one logging apparatus disposed in a wellbore, the logging apparatus including multiple segments, the segments including at least one buoyancy control device and at least one sensor that senses a well parameter, and the segments being helically arranged in the wellbore.

Abstract: An apparatus for sensing acoustic waves below a surface of the earth includes an optical fiber disposed below the surface of the earth and having a series of sensing units along the optical fiber with each sensing unit having three or more reflectors and an optical interrogator in optical communication with the optical fiber. The reflectors in each sensing unit are positioned to provide a linearized response that approximates a sawtooth wave better than a sinusoidal wave to sense the acoustic waves in a desired dynamic range. The optical interrogator is configured to transmit an input light signal into the optical fiber and receive a reflected light signal from the optical fiber due to the input light signal in order to measure a strain on each sensing unit due to interaction with the acoustic waves and to determine a location of the sensing unit corresponding to the sensed strain.

Abstract: A system of and method for determining whether a liquid moving in an oil-bearing reservoir rock formation is water or oil is provided. The oil-bearing rock formation includes at production well(s) and source(s) of injected water during normal oil production. A fluid pathway is identified, baseline number of passive microseismic events is established, passive microseismic events in the fluid pathway are monitored during oil production to sense microseismic events, the sensed microseismic events are compared to a baseline number of passive microseismic events. The fluid causing the microseismic events is determined to be water if the sensed number of microseismic events approaches the baseline number of passive microseismic events per the predetermined unit, and if the baseline number of passive microseismic is measured during a time period when the water injection is greater than the rate of water injection during normal oil production.

Abstract: Methods and related apparatus pertaining to downhole and surface telemetry, such as a method in which a telemetry system is provided with a communication path formed with an electrically conductive transport medium coupled across a plurality of downhole nodes. Such method includes operating on the communication path with a multi-drop system that provides telemetry to the downhole nodes in a wellbore, including employing modulation in a master-slave arrangement using binary differential phase shift keying or differential quadrature phase shift keying.

Abstract: A downhole equalization assembly permits selective and remote opening of at least one downhole port or pathway to allow communication of pressure and/or fluid flow from inside a pressure containing system (such as, for example, a tubular pipe or other pressure containment system) to the outside of the containment system, or vice versa. A control device generating a magnetic field is inserted into a well and conveyed to a downhole equalization assembly. When the control device passes through an equalization assembly, an electronic counter is triggered. When a predetermined counter number is reached, a sliding sleeve is shifted, thereby exposing ports and/or pathways extending between the inside and outside of the equalization assembly. No physical contact or mechanical interference is required between the control device and any other components in order to actuate the equalization assembly.

Abstract: Autonomous units and methods for downhole, multi-zone perforation and fracture stimulation for hydrocarbon production. The autonomous unit may be a perforating gun assembly, a bridge plug assembly, or fracturing plug assembly. The autonomous units are dimensioned and arranged to be deployed within a wellbore without an electric wireline. The autonomous units may be fabricated from a friable material so as to self-destruct upon receiving a signal. The autonomous units include a position locator for sensing the presence of objects along the wellbore and generating depth signals in response. The autonomous units also include an on-board controller for processing the depth signals and for activating an actuatable tool at a zone of interest.

Abstract: In one aspect an apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a completion assembly that contains a filter section having a tubular with a plurality of through holes filled with a filter material for restricting flow of solid particles through the holes for placement of the filter section across from a zone along the wellbore, a sensor inside the tubular for providing information about a parameter of interest during treatment of and/or production from the zone into the tubular, and a first circuit coupled to the sensor that transmits wireless signals corresponding to measurements made by the sensor to a second circuit that transmits the received signals to the surface.

Abstract: Systems, methods, and mediums may implement obtaining baseline traces of a baseline seismic survey and monitor traces of a monitor seismic survey; employing a computer to align the monitor traces to corresponding baseline traces using an error function having a phase-based component, thereby obtaining an aligned monitor survey; generating with the computer a comparison of the aligned monitor survey to the baseline seismic survey; and using the comparison of the aligned monitor survey to the baseline seismic survey to determine a change in the subterranean hydrocarbon producing reservoir.

Abstract: A method includes in a single trip running a completion system having an internal bore into a wellbore that penetrates a formation zone, the completion system having an upper completion connected to a lower completion, setting an isolation packer forming a barrier above the formation zone, displacing the annulus fluid above the set isolation packer and then setting an upper packer thereby providing a completion barrier above the set isolation packer. The annulus fluid may be displaced prior to setting an upper completion packer.

Abstract: Aspects of the disclosure can relate to a system for tracking fatigue damage experienced by a tool in real-time. The system can include a processor operably coupled to a memory and operable to execute one or more modules to generate master curve fitting coefficients for a connection type associated with a tool component (e.g., a component of a bottom hole assembly). The master curve fitting coefficients can be for a threaded connection master curve, a port hole master curve, and so forth. The processor can also be operable to execute the one or more modules to generate a fatigue calculator for the tool component. The system may receive a real-time trajectory for the tool, determine a curvature from the trajectory of the tool, determine a bending moment based upon the curvature, and determine fatigue damage for the tool component based upon the bending moment using the fatigue calculator.

Abstract: A method of verifying swelling of a swellable material in a well can include connecting a transmitter to a sensor which senses a parameter indicative of degree of swelling of the swellable material, and conveying a receiver into an interior of a tubular string. The transmitter transmits to the receiver an indication of the degree of swelling of the swellable material. A packer swelling verification system can include a swellable material which swells in a well, and a well tool which is conveyed to the packer in the well. The well tool receives an indication of a degree of swelling of the swellable material. A method of verifying whether a swellable material has swollen in a well can include positioning a conductor proximate the swellable material, whereby the conductor parts in response to swelling of the swellable material, and detecting whether the conductor has parted.

Abstract: In some examples, a drillstring includes a plurality of drill pipe sections that are coupled together by a drill pipe joint section structure. The drill pipe sections and the drill pipe joint section structure are acoustically impedance matched. In another example, the drill pipe sections comprise a plurality of different pipe lengths, those lengths being different than a length of the drill pipe joint section structure. A drillstring is constructed of these different lengths of drill pipe and drill pipe joint section structures in a non-periodic manner or random sequence. In another example, the drill pipe sections and drill pipe joint section structure comprise materials having substantially similar acoustic properties.

Abstract: An oil field tubular has a composite material housing within which is located one or more wireless communication devices with a charge storage device for powering the communication device(s). In a disclosed method of installing a wireless communication device upon an oilfield tubular, a prefabricated composite shell formed with an inner skin and outer skin forming an inner space for containing the wireless communication device is applied to a surface of the tubular so as to form a cavity between the surface of the tubular and the prefabricated composite shell, a bonding material is introduced to the cavity and bonding material is cured.

Abstract: Systems and methods for identifying formation boundaries without necessarily obtaining an azimuthal borehole image are provided. A downhole tool may be placed in a wellbore in a geological formation that has a formation boundary. First and second measurements may be obtained at a number of depths of the wellbore. The first measurement may have a first effective penetration length into the geological formation and the second measurement may have a second effective penetration length into the geological formation different from the first effective penetration length. Thus, the first measurement may detect the formation boundary at a first depth and the second measurement may detect the formation boundary at a second depth. Using a difference between the first depth and the second depth, an apparent relative angle between the wellbore and the formation boundary or an apparent formation dip, or both, may be obtained.

Abstract: A modular subsea chemical injection system, comprising a power and communications module, a power and communications umbilical terminator, a power and communications module, a fluid storage module comprising a plurality of fluid storage bays adapted to selectively receive a corresponding plurality of high and/or low flow fluid storage units, a pump module comprising a plurality of pump bays adapted to selectively receive a corresponding plurality of high fluid flow and/or low fluid flow pumps, and a fluid distribution unit in fluid communication with a pump module fluid port can be disposed on a seafloor adjacent to a well site and used to selectively provide low and/or high flow fluid delivery by use of subsea storage and pressure boosting for low flow fluid needs and low flow fluid needs.

Abstract: A control system for generating and utilizing at least one or more addressed datagrams that communicate information to and from devices along piping assemblies comprising; one or more transmitters, one or more receivers, and one or more controllers, wherein the transmitters transmit information via one or more addressed datagrams encoded within a working medium to one or more receivers among the piping assemblies, is described. Transmitters convert datagrams into signals that are transmitted within the working medium and the receivers receive signals from the transmitters and also convert signals from the working medium which is converted back into datagrams. The controllers receive and decode the datagrams so that the controllers selectively communicate and perform logical operations on piping assembly devices according to directions received from the addressed datagrams.

Abstract: A technique facilitates a fracturing operation by maintaining the heterogeneity of proppant fluid as it is injected into reservoir fractures. The technique comprises using a blender to deliver proppant material in a pulsating manner to create pulses of proppant. The pulses of proppant are mixed with a fluid to create a proppant slurry having the pulses of proppant material separated by a second fluid. The proppant slurry is then split between a plurality of pumps which are operated to pump the slurry to a well. To maintain heterogeneity, the pump rates of the pumps are individually adjusted to control dispersion of the pulses of proppant downstream of the pumps and to substantially maintain the separated pulses of proppant material in the slurry. A wide variety of other system adjustments also may be made for enhancing the ability of the overall fracturing system to maintain separated pulses of concentrated proppant material.

Abstract: The present invention includes a strain body having a connecting part and a fixing part, and a first strain detection element disposed on the strain body. The strain body includes a void, and the first strain detection element is disposed between the connecting part and the void.

Abstract: Described herein are devices, systems, and methods for analyzing multi-phase fluid flow profile and flow field distribution by utilizing heating wires and thermal sensing arrays to detect transient thermal response and generate a dynamic temperature profile. The thermal sensing arrays include a plurality of thermal sensors disposed linearly along the length of the array. The multi-point dynamic temperature profile is used to determine fluid rate, velocity, flow patterns, and flow field distribution.

Abstract: System and methods of generating calibrated downhole images of a subterranean formation (110) surrounding a wellbore (105). The method involves measuring open hole and cased hole measurements with a downhole tool (132); determining (698) open hole parameters (e.g., Z90) from the cased hole parameters, known parameters and the open hole measurements; and generating (699) downhole outputs from the determined open hole parameters.

Abstract: A multifunctional end cap assembly for use in terminating the toe end of subsurface coiled tubing strings that include multiple sensors. The assembly includes provisions for turnarounds for DTS or DAS systems as well as provisions for connecting formation pressures with a pressure transducer within the coiled tubing string.

Abstract: A control system for generating and utilizing at least one or more addressed datagrams that communicate information to and from devices along piping assemblies comprising; one or more transmitters, one or more receivers, and one or more controllers, wherein the transmitters transmit information via one or more addressed datagrams encoded within a working medium to one or more receivers among the piping assemblies, is described. Transmitters convert datagrams into signals that are transmitted within the working medium and the receivers receive signals from the transmitters and also convert signals from the working medium which is converted back into datagrams. The controllers receive and decode the datagrams so that the controllers selectively communicate and perform logical operations on piping assembly devices according to directions received from the addressed datagrams.

Abstract: Disclosed herein methods for determining a property of a formation, for example, when well logging, by feeding a gadolinium tracer fluid into the formation, applying an emitted radiation to the formation to thereby produce a signal, such as a neutron signal, and capturing the signal from the formation.

Abstract: A data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, on each of the three conductors of a three phase cabled connection with an isolation mechanism operable to isolate any given conductor when a fault associated with that conductor is detected. With the system providing a separate AC signal and data transfer on each conductor isolation can be achieved while enabling continued operation.

Abstract: An acoustic telemetry method for use with a subterranean well can include positioning a well tool in the well, the well tool including an acoustic transmitter and a sensor, and an acoustic receiver in the well receiving an acoustic signal transmitted by the transmitter, the acoustic signal including information representative of a measurement by the sensor. A system for use with a subterranean well can include a well tool positioned in the well, the well tool including an acoustic transmitter and a sensor, the acoustic transmitter transmits an acoustic signal including information representative of a measurement by the sensor to an acoustic receiver positioned in the well.

Abstract: A downhole tool actuation system comprises a control line in fluid communication with a control fluid source, a first piston assembly comprising a first surface in fluid communication with the control line, and a damper piston assembly comprising a second surface in fluid communication with the first surface. The first piston assembly is configured to actuate the downhole tool.

Abstract: A downhole well fluid sensing device is disclosed for determining thermal conductivity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the elongate body and the sampling space having a common longitudinal center axis. The elongate body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

Abstract: A logging while drilling tool for measuring a geological formation surrounding a wellbore includes a tool body having one or more sensor pads. Each sensor pad is coupled to the tool body by an extendable coupling that is operable to adjust the radial position of the sensor pad by extending away from or retracting toward the tool body. One or more sensors are mounted to each sensor pads and the sensors are operable to obtain a measurement a property of the formation. The tool also includes a downhole control unit having a transmitter and receiver. The downhole control unit is operable to receive the measurement and transmit the measurement to a surface controller, wherein the transmitted measurement indicates a measurement resolution.

Abstract: Downhole fluid sensing device is disclosed for determining heat capacity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the sensor package and the sampling space having a common longitudinal center axis. The elongate sensor package body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate sensor package body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices (located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

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

Abstract: A method for using an optical spectrum of mud filtrate for analysis of fluid drawn from a formation is provided. The method includes performing downhole fluid analysis of formation fluid drawn at a wellbore measurement station and determining an optical spectrum of mud filtrate in the formation fluid drawn at the wellbore measurement station. The method also includes performing downhole fluid analysis of formation fluid drawn at an additional wellbore measurement station, and performing the downhole fluid analysis of formation fluid drawn at the additional wellbore measurement station includes using the determined optical spectrum of the mud filtrate in the formation fluid previously drawn at the wellbore measurement station. Additional methods, systems, and devices are also disclosed.