Abstract: A method of identifying a steering command for a rotary steerable system (“RSS”) that includes identifying, by one or more processors, a solution arc for an upcoming drilling segment; automatically identifying, by the one or more processors and in response to the identification of the solution arc, the steering command for the RSS; and automatically identifying, by the one or more processor and in response to the identification of the steering command, downlink commands to be sent to the RSS. Automatically identifying, by the one or more processors and in response to the identification of the solution arc, the steering command for the RSS comprises: accessing a table that models a relationship between dogleg severity and a percentage of steering force; and identifying, using the table, the target steering force associated with the target dogleg severity.

Abstract: A technique facilitates precision fluid conveyance and placement to one or more desired locations in a borehole, e.g. a wellbore. According to an embodiment, a material container, e.g. a fluid container, and/or a fluid flow path system may be deployed downhole via coiled tubing. A release system is selectively actuatable to release a specific amount or amounts of material, e.g. treatment fluid, at the one or more desired locations along the borehole. Depending on the application, various discharge mechanisms and/or supply mechanisms may be used in cooperation with the material container and/or fluid flow path system to provide the precision fluid conveyance and placement.

Abstract: Systems and methods include a method for generating a real-time permeability log. Historical mud gas-permeability data is received from previously-drilled and logged wells. The historical mud gas-permeability data identifies relationships between gas measurements obtained during drilling and permeability determined after drilling. A formation hydrocarbon mobility model is trained using machine learning and the historical mud gas data. Real-time gas measurements are obtained during drilling of a new well. A real-time permeability log is generated for the new well using the formation hydrocarbon mobility model and real-time gas measurements.

Abstract: Methods, systems, and apparatuses for determining the location or depth in a wellbore of a tubular string or downhole component is provided. One method may include placing a tubular string having a depth measurement module into a wellbore, the wellbore emanating radiation at at least one location along the wellbore and determining the location of the depth measurement module in the wellbore based on a correlation between a wellbore property that is a function of depth and a radiation intensity at at least one location within the wellbore.

Abstract: A method of determining a presence of a leak in a wall of a production tubing string includes positioning an electrical submersible pump is positioned at the string's downhole end. Based on measurements from a pressure sensor positioned at a downhole location at a discharge end of the electrical submersible pump, it is determined that a discharge pressure has decreased over a specified time period. Based on measurements from a pressure sensor within a wellhead of the well, it is determined that a pressure within the production tubing string at the surface has decreased over the specified time period. Based on measurements from a flow-rate sensor at an uphole end of the production tubing string, it is determined the flow rate has decreased relative to a calculated expected flow rate. Based on a pressure integrity test initiated in response to these determinations, the presence of the leak is determined.

Abstract: A system for providing information through a metal wall employs a device adapted to be arranged on one side of the metal wall and a magnetic-permeability element, provided at, near or connected to the device. The magnetic-permeability element is based on a material having a relative magnetic permeability of at least 2000. The disclosure also provides use of said system. The use may involve the step of optimizing the magnetic-permeability element using equivalent inductive mass (EIm). The system can for example be used to magnetically sense the location of a cable present on the outside of a wellbore tubular using a magnetic orienting tool that is located within the wellbore tubular.

Abstract: A logging system and method for operating a logging system are typically used in a wellbore. The logging system may include a logging instrument including a rechargeable energy storage and logging electronics, and a cable configured to trickle charge the rechargeable energy storage. The rechargeable energy storage may include an ultracapacitor. The rechargeable energy storage may be trickle charged through the cable from a remote power source.

Abstract: Potential energy conversion systems include a movable mass suspended by a line in a non-producing well, the line being coupled to a motor operable to lift the movable mass, and a generator operable to produce electricity when lowering the movable mass. Energy conversion methods include providing the potential energy conversion system; and storing potential energy by raising the movable mass, or releasing potential energy and converting the potential energy to electricity by lowering the movable mass.

Abstract: The present invention discloses a method for lowering an oil pipe in a gas well without well-killing, a soluble bridge plug and a material preparation method thereof, wherein, the method comprises the steps of: lowering a bridge plug in a wellbore such that the bridge plug blocks the wellbore at a predetermined location in the wellbore; injecting water in the wellbore after the pressure in the wellbore has been relieved so as to replace gases in the wellbore; and lowering an oil pipe in the wellbore to the location of the bridge plug. The method for lowering an oil pipe in a gas well without well-killing, the soluble bridge plug and the material preparation method thereof provided in the present invention successfully solve the problem of high cost for lowering an oil pipe under pressure after a fracturing fluid has been injected into the casing.

Abstract: Methods and systems for monitoring conditions within a wellbore of a subterranean well include extending a drill string into the subterranean well from a terranean surface. The drill string has an actuator assembly, a sensor compartment, and a plurality of sensors located within the sensor compartment. The actuator assembly is instructed to transmit a swarm release signal to a central power unit of the sensor compartment so that the central power unit of the sensor compartment releases certain of the plurality of sensors from the sensor compartment. Data from the sensors is transferred to a data processing system after the sensors reach the terranean surface.

Abstract: A method of imaging a wellbore casing using an ultrasonic sensing system through the material of a drill string as the drill string is tripped out of the wellbore.

Abstract: In some embodiments, a system may include a tool drill string having a downhole device. The system may include a contact module including a first component. The first component may include a first data path capable of communicating data using a first communication protocol, a second data path capable of communicating the data using a second communication protocol, and a processor electrically connected to the first data path and the second data path. The processor may be capable of selectively routing the data between the first data path and the second data path.

Abstract: Disclosed herein are compositions and methods for reducing fluid loss in a well bore. Also disclosed herein are methods for wellbore strengthening and increasing the integrity of the borehole of an oil or gas well. In particular, disclosed are methods for artificially increasing the temperature of a subsurface formation in the wellbore to increase the apparent wellbore strength.

Abstract: A positioning device for adjusting an axial position of a tool within a wellbore includes an anchor configured for attachment to the wellbore at a fixed axial location within the wellbore, a shaft coupled to the anchor, and a coupling member to which the tool is rigidly attached. The coupling member is configured to be translated along the shaft to adjust the axial position of the tool with respect to the fixed axial location of the anchor within the wellbore.

Abstract: A logging system and method for operating a logging system are typically used in a wellbore. The logging system may include a logging instrument including a rechargeable energy storage and logging electronics, and a cable configured to trickle charge the rechargeable energy storage. The rechargeable energy storage may include an ultracapacitor. The rechargeable energy storage may be trickle charged through the cable from a remote power source.

Abstract: A system, in some embodiments, comprises: a light source; a fiber optic cable coupled to surface equipment and to downhole equipment and illuminated with fixed-wavelength light by said light source; and a modulator to modulate said fixed-wavelength light in the fiber optic cable to communicate data between the surface equipment and the downhole equipment, wherein the modulator uses a modified half-duplex telemetry scheme.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a non-polar oil, water, and glycerin. The base fluid may further include a polar oil and an alkylene carbonate. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit.

Abstract: A system and method for improving integrity of a cased wellbore. The method comprises identifying at least one weak plane corresponding to a highest probability of slip of fault within the open-hole wellbore. Further, the method comprises providing pressurized fluid into the open-hole wellbore to cause the slip of the fault by inducing tensile or shear failures within the open-hole wellbore along the at least one weak plane. The method also comprises restoring a shape of the open-hole wellbore after the slip of the fault by removing material from an inner surface of the open-hole wellbore, to provide a uniform or smooth cross-section along an elongate axis of the open-hole wellbore. The method further comprises arranging and cementing a casing along the restored open-hole wellbore to obtain the cased wellbore having improved integrity.

Abstract: An apparatus is directed relative to geomagnetic and gravitational fields of reference while advancing with rotation in a borehole by determining angular position of the apparatus during the rotation and correcting the angular position of the apparatus relative to an offset of a toolface of the apparatus. To do the correction, a magnetic toolface of the apparatus during the rotation is determined based on geomagnetic readings of the apparatus in each of a plurality of divisions of the rotation relative to the geomagnetic field, and a gravitational toolface of the apparatus during the rotation is determined based on gravitational readings of the apparatus in each of the divisions of the rotation relative to the gravitational field. The offset of the toolface is then calculated as a difference between the magnetic toolface and the gravitational toolface. The corrected angular position can then be used in directing the apparatus.

Abstract: The invention describes a method for creating a digital archive for information generated in drilling and well operations, as well as for planning such operations. The invention further describes a system for linking, storing and accessing the information in a data store, and graphical user interfaces enabling users to accessing information made available in the system. The described system allows internet based (cloud), thus allowing users to access information from different physical and virtual location.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a polar oil, a non-polar oil, or a combination thereof and glycerine carbonate. The electrocrushing drilling fluid or base fluid may further include water or glycerin. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit.

Abstract: A system disclosed herein is for determining position of a distal end of a tubular string in a wellbore formed in a subsurface formation. The system includes casing lining the wellbore, with the casing carrying a plurality of radioactive sources. A tubular string is disposed in the wellbore and carries a radiation sensor along a length thereof. A processor is associated with the radiation sensor, and is configured to measure intensity of radiation received from the plurality of radioactive sources, and determine the position of the distal end of the tubular string by correlating a formation or wellbore fluid property that varies as a function of position within the wellbore and the measured intensity of the radiation received from the plurality of radioactive sources.

Abstract: An apparatus and a method for testing performance of an electrosurgical tool include a frame, a clamp module coupled to the frame and configured to retain a test material in a selected orientation, and a tool module coupled to the frame and configured to grip an electrosurgical tool. The apparatus is configured to: (a) allow a user to perform a controllable cut to evaluate a cutting performance of the electrosurgical tool based on a resistance force between the electrosurgical tool and the test material as the electrosurgical tool performs the controllable cut; and (b) evaluate a non-stickness of the electrosurgical tool after the electrosurgical tool performs the controllable cut.

Abstract: A thermodynamic boiler for exchanging (providing or drawing) heat with a heating circuit includes a thermal compressor. The thermal compressor acts on a compressible fluid and includes at least one compression stage, with an alternating bi-directional piston separating a first chamber and a second chamber, and a first fuel burner forming a heat source coupled to the first chamber. The thermal compressor uses the heating circuit as a cold source coupled to the second chamber and forms the compression function of a reversible heat pump type loop.

Abstract: A rotary actuator operates an inflow control device in a tubing string. The rotary actuator includes a stationary member, a drive member, and a locator device, where the locator device anchors the rotary actuator at a predetermined location in a tubing string. The drive member rotates relative to the stationary member, and operates the inflow control device. A method of actuating an inflow control device with a rotary actuator, the method comprising: conveying the rotary actuator to a predetermined location in the tubing string, engaging the engagement members with a profile, thereby preventing further movement of the rotary actuator into the tubing string, and rotating the drive member relative to the stationary member, thereby actuating the inflow control device.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a polar oil, a non-polar oil, or a combination thereof and glycerine carbonate. The electrocrushing drilling fluid or base fluid may further include water or glycerin. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit.

Abstract: A method for processing sonic data measured with a downhole tool is provided. The method comprises acquiring dipole wave data measured by a dipole acquisition in multiple firing, and estimating at least one of formation anisotropy properties based on the multiple firing dipole data. The at least one of formation anisotropy properties may be derived by Alford rotation processing. The method may further comprise processing with inversion of an orthogonality error angle of the firing data in two dipole firings and/or providing a quality control with the estimating result based on sonic measurements in a pump-off period.

Abstract: Methods, systems and devices for evaluating an earth formation, including an electromagnetic (EM) well logging apparatus for investigating a formation from a fluid-filled borehole intersecting the formation. Apparatus include a carrier body having a pocket formed in an outer surface, the pocket being defined by a plurality of walls and a bottom; a pad configured to emit EM energy, the pad having an outer face, a plurality of sides complementary to the plurality of walls, and an inner face positioned adjacent to the bottom, wherein the pad is movably disposed in the pocket such that a gap separates at least one wall of the plurality of walls and at least one side of the plurality of sides; and at least one electrically conductive member forming an electrical connection between the carrier body and the pad and covering the gap. The pad may be slideably disposed in the pocket.

Abstract: Surface treated modified carbon black particles and oil-based drilling fluids are described. The carbon blacks are incorporated into the oil-based drilling fluids to reduce the electrical resistivity of the oil-based drilling fluids. The surface treated carbon blacks can include a hydrophobic organic group and are readily dispersible in oil-based drilling fluids.

Abstract: A method for adjusting a parameter of a wellbore operation includes: conveying a carrier through the wellbore; performing a resistivity measurement on the formation using a resistivity tool disposed on the carrier; performing an acoustic measurement on the formation using an acoustic tool disposed on the carrier; generating with a at least one processor a map of the formation using the resistivity measurement and the acoustic measurement, and adjusting the parameter using the map.

Abstract: A production casing string including a plurality of propellant sleeves positioned on an exterior of the production casing string, and each propellant sleeve includes a firing mechanism and a firing sleeve for selectively covering and uncovering the firing mechanism. The casing string also includes an identifiable marker associated with each propellant sleeve and at least one selective bi-directional valve assembly associated with each propellant sleeve.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a non-polar oil, —OH, —(OH)2, or —(OH)3 alcohol, water, and an emulsifier in proportional amounts by weight or volume in that order. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity or viscosity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit and a method of electrocrushing drilling.

Abstract: Tools and methods for monitoring a subterranean formation is provided. Methods for monitoring include: creating a time-lapse azimuth stack between an azimuth stack on a first seismic survey and an azimuth stack on a second seismic survey; identifying a lowest root mean square energy and a highest root mean square energy for each time-lapse azimuth stack; and recording an azimuth with largest overall root mean square energy.

Abstract: A drilling system, comprising a drill string; and a ranging tool mounted on the drill string, the ranging tool comprising a magnetic sensor pair comprising a first magnetic sensor and a second magnetic sensor mounted radially opposite one another on the ranging tool, wherein each of the magnetic sensors is structured and configured to detect at least a radial component and a tangential component of a magnetic field; a rotatable assembly, comprising a motor structured and arranged to actuate rotation of the magnetic sensor pair around the drill string; and an electronics package connected to at least one of the magnetic sensor pair, and the motor, wherein the electronics package comprises a controller and a wireless telemetry device.

Abstract: An apparatus and method may operate to mount acoustic sensors, azimuthally offset from each other, to the exterior of a casing. After the casing and acoustic sensors are in the borehole, signals are provided to the acoustic sensors to cause the acoustic sensors to emit acoustic signals into the annulus around the casing. The method further includes detecting reflected compression waves, shear waves or a combination or conversion thereof at the acoustic sensors to generate a set of two]way travel times of the acoustic signals. The method can further include generating distance measurements of a distance between corresponding acoustic sensors and points on the borehole wall based on the two]way travel times, to determine a position of the casing within the borehole. The method can further include identifying fluids based on the two]way travel times. Additional apparatus, systems, and methods are disclosed.

Abstract: A disclosed pressure determination method for tight gas formations includes: obtaining a downhole core sample of a tight gas formation penetrated by a borehole, the core sample having been sealed in a pressure-maintaining core vault during transport out of the borehole; determining an effective pore space of the core sample; deriving the number of moles of gas retrieved with the core sample; and combining the effective pore space and the number of moles together with a downhole temperature to get an estimated formation pressure. A system embodiment includes: a core vault that provides pressure-preserved transport of a core sample from a tight gas formation; a collection chamber that attaches to the core vault to measure volumes of liquid and gas fluids from the core sample; and a processing unit that determines an estimated formation pressure based on said volumes, a downhole temperature, and an effective pore space of the core sample.

Abstract: Onshore electromagnetic (EM) reservoir monitoring systems and methods, including a system with a light source producing a light beam and an EM sensor array positioned above ground or buried underground over one or more regions of interest within a subterranean formation, the array coupled to the light source with an optical fiber. An EM sensor modulates the interrogation light beam in response to an EM signal induced into the subterranean formation by an EM source. The system further includes a processor controlling the light source, processing modulated light received from the array, and collecting data with the array to produce EM surveys, each EM survey based on data sets collected at different times. The EM sensor is physically isolated from a surrounding environment. The surveys are combined to produce a time lapse earth model of the regions of interest.

Abstract: Systems, devices and methods for evaluating an earth formation intersected by a borehole. Method include detecting a reflective boundary in the earth formation by: generating a multipole acoustic signal with a logging tool in the borehole; identifying a shear wave signal resulting from shear body waves reflected in the formation in a near-field region of the formation around the borehole responsive to the generated multipole acoustic signal; and estimating at least a depth along the borehole of the boundary based on the shear wave signal. The boundary may have an angle of incidence with respect to the borehole of greater than 70 degrees. The boundary may be at least one of i) a fracture; and ii) a fault. The method may include evaluating the boundary using at least one attribute of the shear wave signal and the estimated depth.

Abstract: Disclosed are methods and apparatus obtaining in-situ, real-time data associated with a sample stream obtained by a downhole sampling apparatus disposed in a borehole that extends into a subterranean formation. The obtained data includes multiple fluid properties of the sample stream. The sample stream includes native formation fluid from the subterranean formation and filtrate contamination resulting from formation of the borehole in the subterranean formation. The obtained data is filtered to remove outliers. The filtered data is fit to each of a plurality of models each characterizing a corresponding one of the fluid properties as a function of a pumpout volume or time of the sample stream. Based on the fitted data, a start of a developed flow regime of the native formation fluid within the subterranean formation surrounding the borehole is identified.

Abstract: A downhole fluid testing system includes a downhole acquisition tool housing configured to be moved into a wellbore, where the wellbore contains fluid that comprises a native reservoir fluid of a geological formation and a contaminant. The system includes a pump to pump fluid through the downhole acquisition tool, a sensor configured to analyze portions of the fluid and obtain a fluid property the fluid from an optical spectrometer, including an optical density, and a controller coupled to the housing to receive a first plurality of measurements over time from the sensor, estimate a future saturation pressure of the fluid at specific time increments via a processor based in part on the first plurality of measurements and a saturation pressure model, and control a flow rate of the pump that causes the flow line pressure to remain above the estimated future saturation pressure plus a value of the associated uncertainty.

Abstract: An impact dissipation tool for supporting a downhole tool in downhole applications. The tool includes a base and a housing. The tool also includes a carriage located within the housing and coupled to the base, the carriage being movable relative to the housing upon a predetermined impact force. A dissipator disposed inside the housing is collapsible due to the relative movement of the carriage and the housing. The collapse of the dissipator dissipates the impact force transferred to the downhole tool.

Abstract: A remotely deployed untethered device for actuation of a downhole application. The device may be equipped with inductive measurement capacity for interaction with a downhole well architecture. Such capacity affords the ability to trigger an actuation remotely at a site specific location in the well without further intervention relative surface equipment.

Abstract: Methods of locating a loss zone in a wellbore in a subterranean formation including determining a calculated wellhead pressure, calculating a wellhead pressure differential, calculating a flow rate loss, estimating a loss zone depth, determining a modified calculated wellhead pressure, and calculating a modified wellhead pressure differential until the modified wellhead pressure differential corresponds to a loss zone location in the wellbore.

Abstract: A method of creating a synthetic aperture. The method may comprise identifying a static configuration, inputting the static configuration into a dynamic controller, configuring a transmitter with the dynamic controller, and configuring a receiver with the dynamic controller. The method may further comprise inputting operational variables and environmental variables into a dynamic configuration, inputting the dynamic configuration into the dynamic controller, and re-configuring the transmitter and the receiver with the dynamic controller.

Abstract: A drilling rig apparatus is disclosed for improving geosteering control by reducing the amount of bandwidth necessary to convey log data to the surface in real time. A bottom hole assembly receives measurement data from azimuthal measurement sensors. The BHA sorts the measurement data into appropriate bins in a radial plot. The BHA selects a hemisphere for transmission of the measurement data in those bins for the selected hemisphere, instead of transmitting the data for all bins in the plot. The BHA may average the data in the bins for the selected hemisphere with the data of the mirroring bins in the non-selected hemisphere. The BHA transmits the measurement data to a surface controller, which mirrors the data transmitted to the corresponding bins in the non-selected hemisphere to reconstitute the full set of data for the radial plot, which is used for image log generation, geosteering and other control functions.

Abstract: A magnetic nanoparticle suitable for imaging a geological structure having one or more magnetic metal or metal oxide nanoparticles with a polymer grafted to the surface to form a magnetic nanoparticle, wherein the magnetic nanoparticle displays a colloidal stability under harsh salinity conditions or in a standard API brine.

Abstract: A wellbore servicing system comprising a controller node disposed within a wellbore, and a tool node configured for movement through the wellbore, wherein the tool node communicates with the controller node via a near field communication (NFC) signal, wherein prior to communication with the controller node, the tool node will not perform at least one function and, after communication with the controller node, the tool node will selectively perform the at least one function.

Abstract: A downhole tool having opposing interfaces for incorporation of the downhole tool into a downhole tool string, and a housing extending between the opposing interfaces. An accelerometer is disposed within the housing for detecting acceleration of the downhole tool in response to a mechanical impact generated elsewhere within the downhole tool string. The accelerometer generates an accelerometer signal indicative of the detected acceleration. A strain sensor is disposed within the housing for detecting strain of the downhole tool. The strain sensor generates a strain signal indicative of the detected strain. The downhole tool includes a processor for processing the accelerometer signal utilizing the strain signal.

Abstract: An apparatus for installing two sensing instruments and cables inside of a single tubing string in a wellbore for monitoring well conditions at two different locations includes an upper sensor attached to an inner sleeve seated at a first location in a ported outer sleeve in the tubing string. The upper sensor is allowed to be in pressure communication with the exterior of the tubing string at the first location. A second lower sensor is deployed on a pump down cup (PDC) assembly to a lower depth in the outer sleeve to allow fluid pressures to be monitored at a second location in the wellbore.

Abstract: A data retrieval device for communicating between a downhole location within a wellbore (16) and a surface location (22) in which a downhole to surface telemetry system is installed and adapted to communicate between a first telemetry module and a second telemetry module with the second telemetry module (18) positioned downhole and connected to a string (12) positioned within the wellbore (16). The data retrieval device is provided with a housing adapted to be positioned inside the string; a communication device supported by the housing; a connection port positioned on the housing and adapted to be connected to a line; and an electronic module supported by the housing. The electronic module is in communication with the communication device and is adapted to store and use at least an identification parameter of the first telemetry module to intercept a signal transmission addressed to the first telemetry module from the second telemetry module (18) via the communication device.