Abstract: A technique facilitates providing a downhole completion with electrical power. The technique may comprise placing an independent completion in a wellbore section. The independent completion is provided with a removable power unit having a power generator coupled to a power storage device. The technique further comprises communicating data or other signals between the independent completion located in the wellbore section and a second completion located in a separate wellbore section.

Abstract: In one aspect, an apparatus for use downhole is disclosed that in one configuration includes a downhole device configured to be in an active position and an inactive position and an actuation device that includes: a housing including an annular chamber configured to house a first fluid therein, a piston in the annular chamber configured to divide the annular chamber into a first section and a second section, the piston being coupled to a biasing member, a control unit configured to enable movement of the first fluid from the first section to the second section to supply a second fluid under pressure to the tool to move the tool into the active position and from the second section to the first section to stop the supply of the second fluid to the tool to cause the tool to move into the inactive position.

Abstract: A method of monitoring a solenoid (1) of a directional control valve (DCV) associated with a subsea control module (6) in a subsea hydrocarbon production system is disclosed. A voltage is applied across a coil of the solenoid, for moving the armature (4) thereof, and a current through the coil is sensed to produce an indication of if and when the armature is moved.

Abstract: A method for determining depth in a wellbore uses inertial navigation in conjunction with a database having one or more measured parameters correlated with depth. The measured parameter may be the lengths of stands forming a drill string, prior survey data relating to a naturally occurring feature such as formation lithology, or data relating to a human made feature such as collars in a casing string. The downhole processor may use accelerometer measurements to calculate a measured depth of a BHA and access the database to retrieve a predicted depth that corresponds with one or more sensor measurements (e.g., motion indicating the addition of a stand to a drill string). Thereafter, if the downhole processor determines that the predicted depth is in agreement with the calculated depth, the processor stores the predicted depth and/or associates the predicted depth with directional surveys taken along the wellbore.

Abstract: A drilling tool having memory to store measured data, a transceiver and an embedded antenna, where a transceiver is lowered into the bore of the drilling tool to receive a radio signal from the drilling tool transceiver to receive the stored measured data. Data may also be transmitted from the lowered transceiver to the drilling tool transceiver. Various methods may be employed to cause the transmitter to transmit the stored measured data while the drilling tool is still in the borehole. Other embodiments are described and claimed.

Abstract: A downhole tool with a feedback arrangement including a tool having one or more fluid outflow ports that exhaust fluid during normal operation of the tool. A feedback arrangement in operable communication with the fluid exhausted from the one or more fluid outflow ports during operation of the tool. The feedback arrangement interacting with exhausting fluid to produce a signal receivable at a remote location indicative of proper tool operation. A method for confirming operation of a downhole tool is included.

Abstract: A downhole tool configured for conveyance within a borehole extending into a subterranean formation, wherein the downhole tool comprises a sensor assembly comprising a housing, a cap coupled to an end of the housing, a flow-line tube disposed within the housing and configured to receive fluid from the formation, a first winding disposed within the housing and configured to induce an electrical current in the fluid, and a second winding disposed within the housing and configured to detect the electrical current induced in the fluid by the first winding.

Abstract: A sensor used to determine the height of one or more fluids in a fluid column and to determine a location of an interface or boundary between a plurality of fluids in a fluid column is disclosed. The sensor includes a plurality of sensing elements comprising a capacitor and other components, such as resistors and inductors. The sensor also includes an oscillator that alters a frequency of an electrical current applied to the sensor, from which the dielectric constant of the fluid in which each sensing element is disposed can be determined. Methods of using such a sensor to determine the relative heights of various fluids in a fluid column are disclosed. In particular, methods of using embodiments of the invention in a well, such as water and petroleum wells, are described.

Abstract: Construction of well screens utilizing pre-formed annular-shaped elements. A well screen includes a filter layer configured to filter fluid flowing through the well screen and a drainage layer which radially supports the filter layer, the drainage layer including multiple individual annular-shaped elements. Another well screen includes a drainage layer configured to support the filter layer, with the drainage layer including at least one cavity molded therein. Another well screen includes a base pipe and a layer made up of multiple individual annular-shaped elements stacked coaxially on the base pipe. A cavity is formed in at least one of the elements.

Abstract: A method of flowing fluid from a formation, the method comprising: sensing presence of a reservoir impairing substance in the fluid flowed from the formation; and automatically controlling operation of at least one flow control device in response to the sensing of the presence of the substance. A well system, comprising: at least one sensor which senses whether a reservoir impairing substance is present; and at least one flow control device which regulates flow of a fluid from a formation in response to indications provided by the sensor.

Abstract: Methods and related systems for use with a wireline tool system. A wireline cable designed to deploy a wireline tool into a wellbore from a surface. The wireline cable includes one or more conducting members for communication between the wireline tool and the surface. A plurality of sensing elements located on the wireline cable in a spaced apart fashion along a length of the wireline cable, wherein each sensing element is in communication with one or more adjacent sensing element.

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

Abstract: Systems and methods for determining at least one parameter of a fluid in a well are provided. The system has a downhole system deployable into the well, and sensor elements to measure fluid parameter(s) of the fluid in the well. Each of the sensor elements is provided with a base and sensors. The base is positionable on the coiled tubing system about the injection port. The sensors are positionable in the base. Each of the sensors are thermally isolated from each other, and are capable of operating as both a heater to heat the fluid, and as a temperature sensor for measuring a temperature of the fluid. The sensors are operatively interchangeable such that the sensors may selectively heat and measure the temperature of the fluid whereby fluid parameters of the fluid are determined.

Abstract: A completion system for use in a well includes a first completion section and a second section. The first completion section has a sand control assembly to prevent passage of particulates, a first inductive coupler portion, and a sensor positioned proximate to the sand control assembly that is electrically coupled to the first inductive coupler portion. The second section is deployable after installation of the first completion section. It includes a second inductive coupler portion to communicate with the first inductive coupler portion, to enable communication between the first completion section's sensor and another component coupled to the second section.

Abstract: A technique facilitates recovery of hydrocarbons in subterranean formations by simplifying the joining of completion assemblies downhole. The system and methodology utilize a well completion having completion assemblies that may be selectively engaged downhole without requiring precise positional accuracy for each signal communication line. A signal communication system is provided to facilitate engagement of the completion assemblies while enabling the transfer of various signals across the connection.

Abstract: A pipeline instrumentation and control system comprising a first electrically insulated radiating cable for controlled radiation and reception of electromagnetic signaling carried to a second electrically insulated radiating cable wherein first and second electrically insulated radiating cables are axially disposed along a production well pipe and wherein first axially radiating cable comprises a section configured to substantially overlap second radiating cable section and further wherein electrical signals present in first radiating cable section is configured to induce a corresponding signal in said second radiating cable section to facilitate the transfer of electromagnetic radiation therebetween. The present invention provides reliable data communication from any location within the production system and improves reservoir management, well planning and resource exploitation.

Abstract: Methods and apparatus for detecting nearby conductors such as pipes, well casing, etc., from within a borehole. A nearby casing string can be detected by transmitting an electromagnetic signal from a first antenna on a downhole logging tool and measuring a response signal with a second antenna. As the tool rotates, the transmitting and measuring are repeated to determine the azimuthal dependence of the response signal. The azimuthal dependence is analyzed to determine an diagonal component and a cross component. The amplitude of the diagonal component is indicative of distance to the conductive feature. Direction can be determined based on the diagonal component alone or in combination with the cross component. Sinusoidal curve fitting can be employed to improve accuracy of the distance and direction estimates. At least one of the antennas is preferably tilted. Measurement results are presented for parallel tilted and perpendicular tilted antennas.

Abstract: The present invention provides a conveyance tool and a tool string having one or more sensors or cameras for detecting the performance of pre-existing perforations in a cased wellbore, and one or more perforation intervention tools mounted on the tool string and capable of performing remedial actions directed at most one perforation and its nearest neighbors or at a single perforation.

Abstract: Downhole orientation sensing with a nuclear spin gyroscope. A method of sensing orientation of an instrument assembly in a subterranean well can include incorporating an atomic comagnetometer and an optical source into the instrument assembly, and installing the instrument assembly in the well. A downhole orientation sensing system for use in conjunction with a subterranean well can include a downhole instrument assembly positioned in the well, the instrument assembly including an atomic comagnetometer and an optical source which transmits light to the atomic comagnetometer.

Abstract: The present disclosure relates to one or more methods and apparatus to dispose one or more markers within a subterranean formation. The method includes positioning a drill probe assembly in a borehole extending into the subterranean formation, drilling a hole through a sidewall of the borehole with a flexible shaft of the drill probe assembly, the hole penetrating the subterranean formation, and disposing a marker in the hole.

Abstract: A drill bit string has an internal steering module for measurement while drilling. A chassis is inserted into a modified drill collar from the axial end, rather than through the side. The chassis has external pockets machined into it from its outer diameter. The size of the longitudinally milled slots in the chassis is determined by the size of the components. The mud flow path is positioned off-center because of the component slots. The geometric shape of the flow path through the tool is shaped to optimize the flow area and maintain a wall thickness that can withstand the mud pressure. The wall thickness surrounding the flow area is proportional to the maximum hydrostatic pressure and the circulation pressure.

Abstract: A method of monitoring acoustic activity in a formation from a wellbore includes positioning a flow manipulation device into the wellbore, the flow manipulation device defining a flow path through which fluid may flow. Fluid is then pumped into the wellbore and through the manipulation device. A sensor disposed near the manipulation device is then coupled to the formation, the formation is fractured with fluid, and acoustic events in the formation are detected with the sensor.

Abstract: Some aspects of the present disclosure include monitoring fluid flow in a subterranean reservoir. In some implementations, a sealant mixture is injected into a subterranean reservoir to form a flow barrier in the subterranean reservoir. The sealant mixture includes a sealant material and a tracer. The tracer may be stored in the flow barrier, and the tracer may be displaced from the flow barrier, for example, by fluid flow in the subterranean reservoir. The displaced tracer may be detected, for example, in fluid produced into a well bore in the subterranean reservoir. Fluid flow in the subterranean reservoir may be analyzed based on detection of the tracer.

Abstract: Data gathering device for in situ gathering of formation data from a borehole wall of a well in an open borehole comprises at least one movable measuring probe structured to be movable out from a well pipe to be able to establish contact with the borehole wall; at least one activation device structured in a manner allowing it to cause said measuring probe movement; at least one measuring sensor which, for measuring at least one formation-associated parameter, is connected to the measuring probe; and at least one data registration device which, for registration of measured parameters, is connected to the measuring sensor.

Abstract: The present invention refers to a method for detecting the geometry of underground fractures comprising the steps consisting of introducing a filling material (14) into an underground fracture (11) to form a pack of filling material (14); transmitting an electromagnetic field into the fracture (11); detecting at least one reflected signal of the electromagnetic field transmitted; and processing the at least one detected signal to reconstruct the geometric and dimensional characteristics of the pack of filling material (14); and it is characterised in that the electromagnetic field transmitted into the fracture (11) has a frequency comprised in the range of between 30 megahertz and 250 megahertz and in that said filling material is not added with any additives. The present invention also refers to a system for detecting the geometry of underground fractures for implementing the aforementioned method.

Abstract: A subsurface formation monitoring system and method is described. The system includes a conductive piping structure positionable within a borehole extending into a subsurface formation. The conductive piping structure is electrically decoupled from a production tubing by an insulating packer. The system also includes a downhole installed conductive casing sub that has one or more sensors. The conductive casing sub is electrically coupled to the conductive piping structure. The system further includes a surface installed power and communication module that has an alternate current generator. The power and communication module is electrically coupled to the conductive piping structure via a downhole intermediate module. The alternate current generator can inject a current signal that flows downhole to the conductive casing sub and then returns with sensor measurements to the surface power and communication module via a grounded return electrode that is coupled to the subsurface formation.

Abstract: Method and apparatus for handling a supported tubular string with a string elevator and a spider on a rig to prevent damaging contact between the string elevator and spider while facilitating further connections of add-on tubular segments. The string elevator and supported tubular string descend toward the spider until reaching a predetermined position. The process of setting the spider into engagement of the tubular string is automatically initiated in response to detecting the predetermined position of the string elevator. With the spider set, the string elevator can be unloaded. Optionally, the method may also automatically terminate the string elevator descent in response to detecting that the spider has been set. A preferred apparatus for detecting the position of the elevator includes a tilt switch secured to a fixed position along the length of the Kelly hose.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to monitor a first condition associated with transmitting or receiving a signal in a formation or on a drill string, or both, over a first selected interval of a drill string located down hole; to monitor a second condition associated with transmitting or receiving the signal in the formation or on the drill string or both, over a second selected interval of the drill string; to compare the first condition to the second condition to provide a comparison result; and based on the comparison result, to select one of the first selected interval or the second selected interval to transmit or receive the signal in the formation or on the drill string, or both. Additional apparatus, systems, and methods are disclosed.

Abstract: Method and apparatus for identifying lost circulation in subterranean wells, in particular, methods for treating the identified lost circulation zones with fluid compositions that are pumped into a wellbore enter voids in the subterranean-well formation through which wellbore fluids escape, and form a seal that limits further egress of wellbore fluid into the lost-circulation zone.

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

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

Abstract: A device and related method for conducting a wellbore operation controls a tool by using at least one pressure estimated at a contact between a reaction surface and a contact face associated with the tool. The device may include a contact face and a sensor associated with the contact face. The sensor may be configured to estimate a pressure applied to the contact face.

Abstract: An electro-mechanical indicator system for signaling when a droppable object (such as, for example, a dart, plug or ball) is released during well cementing operations. A body section has first and second chambers divided by a fluid and pressure sealing barrier. A mechanical trigger mechanism is situated in the first chamber, which is exposed to elevated pressures and harsh wellbore fluids. Less robust components, such as sensor(s), power source(s), and signal device(s) located in the second chamber, remain isolated from the wellbore environment and elevated pressures.

Abstract: A method of signal processing includes providing at least a first pressure sensor and a second pressure sensor spaced in a drilling system and using an algorithm to separate the downwardly propagating waves from the upwardly propagating waves. In one or more examples, an algorithm may include determining a velocity of pressure signals in a wellbore, time-shifting and stacking pressure signals from at least the first pressure sensor and the second pressure sensor to determine a downwardly propagating noise signal, and subtracting the downwardly propagating noise signal from at least the signal from the first pressure sensor.

Abstract: A tool assembly and method for completing a well are provided. The tool includes debris relief features that enable use in solids-laden environments, for example in the presence of sand. Forward and reverse circulation pathways to the isolated interval are present to allow clearing of debris from the wellbore annulus while the sealing device remains set against the wellbore.

Abstract: A technique facilitates use of a through tubing completion system run in a lateral borehole. The through tubing completion may comprise production tubing coupled to a flow control valve and one or more sensors measuring at least one characteristic of the lateral borehole. The through tubing completion also comprises a connection system which facilitates the transfer of signals between the through tubing completion extending into the lateral borehole and a surface location or other location.

Abstract: A technique facilitates monitoring of parameters in a well environment. At least one sensor is positioned downhole in a wellbore to measure a desired parameter or parameters. Data from the sensor is sent uphole to an electrical wellhead outlet which is integrated into the wellhead. The wellhead and integrated electrical wellhead outlet provide a simple system architecture that may be used to process well parameter data as desired.

Abstract: A method of servicing a wellbore, comprising placing a wellbore composition comprising a plurality of Micro-Electro-Mechanical System (MEMS) sensors in the wellbore, placing a plurality of acoustic sensors in the wellbore, obtaining data from the MEMS sensors and data from the acoustic sensors using a plurality of data interrogation units spaced along a length of the wellbore, and transmitting the data obtained from the MEMS sensors and the acoustic sensors from an interior of the wellbore to an exterior of the wellbore. A method of servicing a wellbore, comprising placing a wellbore composition comprising a plurality of Micro-Electro-Mechanical System (MEMS) sensors in the wellbore, and obtaining data from the MEMS sensors using a plurality of data interrogation units spaced along a length of the wellbore, wherein one or more of the data interrogation units is powered by a turbo generator or a thermoelectric generator located in the wellbore.

Abstract: The present document describes a sensing apparatus for lowering into a well and cementing therein at a certain depth. The sensing apparatus comprises an elongated casing and a sensor device protruding from an outside surface of the elongated casing for generating measurement data and sending the data to the surface of the well using a cable extending from the sensor device along the outside surface of the casing. A flow of cement is provided between the outside surface of the casing and the well for cementing the casing in place and isolating different layers of the well. Presence of the sensor device and the cable creates an obstruction within the flow path of the cement which may result in the formation of micro-annulus around the sensor device and the cable.

Abstract: A drill string component includes a downhole power assembly and a center mandrel with a through-bore adapted to accommodate a flow of drilling fluid. The downhole power assembly includes a tubular battery cage disposed around the center mandrel. At least one battery is disposed in at least one bay formed in the tubular battery cage and a tubular sleeve is adapted to slide over and cover the tubular battery cage.

Abstract: Disclosed embodiments include apparatus and methods for transferring a pressure to downhole electronics with a pressure transfer medium. An embodiment of the apparatus includes a body supporting a moveable pressure transfer member, a pressure transfer medium contained by the body and the moveable pressure transfer member, and an electronic component disposed in the pressure transfer medium, wherein the pressure transfer member is moveable to transfer a pressure to the pressure transfer medium and the electronic component. Another embodiment of the apparatus includes a moveable enclosure and a non-conductive material, wherein the non-conductive material isolates an electronic component from a downhole fluid and the moveable enclosure is operable to transfer a hydrostatic pressure to the non-conductive material and the electronic component. An embodiment of a method includes transferring a downhole hydrostatic pressure to an electronic component via a flexible package and a pressure transfer medium.

Abstract: A downhole tool includes a downlinking system deployed in a downhole tool body having an internal through bore. The downlinking system includes a differential pressure transducer configured to measured a pressure difference between drilling fluid in the internal through bore and drilling fluid external to the tool (in the borehole annulus). The differential transducer is electrically connected with an electronic controller (deployed substantially anywhere in the drill string) that is configured to receive and decode pressure waveforms.

Abstract: One embodiment includes an apparatus comprising a surface slip to support drill tubing and having a communications instrument.

Abstract: A method of producing fluids from a wellbore that has therein n adjustable flow control device for controlling flow of fluid between a formation and the wellbore may include: providing a tool having a sensor configured to provide measurements relating to a downhole property of interest, wherein the tool is configured to adjust flow from the flow control device; conveying the tool into the wellbore; determining the property of interest using the tool; and adjusting the flow through the flow control device with the tool at least in part in response to the determined parameter of interest. An apparatus for controlling fluid flow between a formation and a wellbore, according to one embodiment may include: a tool configured to be conveyed into a wellbore that contains at least one sensor for estimating a property of interest downhole and a latching device configured to couple to a flow control device in the wellbore to alter flow of the fluid through the flow control device.

Abstract: A process and system for release and recovery of methane from subterranean methane hydrate deposits in which heated CO2 is used to displace methane from the methane hydrate deposits and a portion of the displaced methane is routed to a combustion device proximate the deposit for combustion in-situ, generating heated CO2 which is introduced into the deposit, displacing additional methane, a portion of which is routed to the combustion device, thereby providing a substantially self-sustaining process. Portions of the displace methane not routed to the combustion device are captured for use elsewhere.

Abstract: A technique that is usable with a well includes deploying a sensing device on a drill string and communicating with the sensing device during a plug cementing operation over a wired infrastructure of the drill string. The technique includes controlling the plug cementing operation in response to the communication.

Abstract: A technique includes wirelessly communicating between a first telemetry unit and a second telemetry unit in a well completion. The communicating causes a leakage current between the first and second telemetry units. The technique includes monitoring the leakage current to detect a change in location of a formation fluid layer.

Abstract: The invention provides a system, method and downhole tool for stimulating a borehole of wells in reservoir. The invention allows a user to determine the type of stimulation adequate to promote production in a reservoir, and apply one or more treatments to each individual well by activating one or more modules comprised in the downhole tools. Furthermore, the tool comprises sensors that collect information in real-time of the state of the reservoir. The data collected is processed and newly acquired data is compared with previously acquired data to assess the development of production and further plan treatment strategies to optimize production.

Abstract: An improved multi-well control system (MWCS) has a centrally based multi-well controller (MWC) in communication with one or more slave controllers and one or more electronic flow measurement devices (EFMs) for instant data monitoring and control of individual wells. The system also provides for an application host sub-system (AHSS) in communication with the MWC for historical and instant data retention. The system is capable of assigning one or more wells to a group for allocation purposes and organizing groups dependent on production levels of individual wells. The MWC is capable of tracking gas volumes produced by each well independent of groupings and communicating such data to the AHSS. The MWC provides monitoring and tracking data from one or more EFM devices and assigns total flow volume to individual wells. The entire MWCS can result in the reduction of manpower and an increase in overall production efficiency.

Abstract: A system and method for determining a downhole parameter is provided. The system has a sensor positionable on a downhole tool. The sensor comprises insulation positionable on a pad of the downhole tool, and return(s) positionable in the insulation, the return(s) adapted to exchange a current with a power source, the return(s) defining a fluid zone. The sensor comprises a mud button positionable within the fluid zone and in the insulation a distance from the return(s), the mud button exchanging current with the return(s). The mud button and the fluid zone are positioned a distance from the formation such that a majority of the current passing between the return(s) and the mud button passes through the downhole fluid whereby the current exchanged with the mud button generates a measurement of the downhole fluid.