Abstract: According to examples, steam breakthrough detection and prevention for a steam assisted gravity drainage (SAGD) well may include accessing real-time data associated with the SAGD well. Parameter values associated with an operation of the SAGD well may be determined based on the real-time data associated with the SAGD well. A potential of occurrence of steam breakthrough may be determined based on an analysis of selected parameter values from the parameter values associated with the operation of the SAGD well. A procedure to prevent the occurrence of the steam breakthrough may be determined based on an application of hypothetical parameter values associated with the operation of the SAGD well to an engineering analysis model associated with the SAGD well. Further, the operation of the SAGD well may be controlled based on the procedure to prevent the occurrence of the steam breakthrough.

Abstract: A screen assembly includes a tubular having a first end, a second end, and an intermediate portion including an outer surface provided with a plurality of openings extending therebetween. At least one screen arranged at the plurality of openings. At least two deformable members are mounted to the tubular between the first end and the second end. The at least two deformable members are selectively radially outwardly expandable relative to the at least one screen forming a plurality of screen compartments on the tubular, the plurality of screen compartments being substantially fluidically isolated from one another externally of the tubular.

Abstract: A method of passing downhole fluids through a screen assembly mounted to a tubular run into a well bore. The screen assembly has a plurality of screen sections arranged at a resource production zone between a first swellable member and a second swellable member. The method includes passing a fluid through an annular screen of the plurality of screen sections into the tubular. At least a portion of the fluid includes particulate matter. Particulate matter is accumulated at the annular screen. Particulate matter is detected in the fluid. The fluid passes into one or more of a plurality of inner screen compartments provided on an inner tubular member radially inwardly spaced from the tubular, and the fluid is filtered through an erosion resistant annular screen of one or more of the plurality of inner screen compartments.

Abstract: A method for controlling fluid flow through a wellbore by introducing a plug with a variable choke into the wellbore, setting the plug in the wellbore, and mechanically adjusting the variable choke in the wellbore, thereby controlling a flow rate of a fluid through the plug. A plug that can control fluid flow through a flow passage in a wellbore, where the plug can include a body, an annular seal element that prevents fluid flow through an annulus between the plug and the wellbore, and a variable choke, where a closure member of the choke is mechanically rotated downhole to adjust a fluid flow rate through the choke. A method that can include producing fluids from two zones and using a plug to control a ratio of the fluids in a produced mixture.

Abstract: Method of simultaneous introducing of two or more than two chemical substances and/or water into a subterraneous hydrocarbon formation and/or control of the rate of chemical reactions of these substances, and a device for implementation of this method This invention relates to the method of simultaneous introducing of two or more than two chemical substances and/or water into a subterraneous hydrocarbon formation and/or control of rate of chemical reactions of these substances and/or water by introducing their controlled amount into a subterraneous formation containing liquid and/or gaseous hydrocarbons, particularly crude oil, shale gas or natural, below a dedicated packer for exploration and production of these hydrocarbons and simultaneous inserting of a dedicated data cable (3) for interconnection of the measuring and/or regulating components in the wellbore, where the said chemical substances and/or water are supplied into the wellbore at controlled rate through the free casing (5) by means of at least t

Abstract: Systems and methods for fracturing an interval of a subterranean formation to produce fluid from a reservoir through a wellbore. A treating fluid flows into the wellbore to create fractures in the formation. A flow constraint material is selectively flowed into the wellbore simultaneously with the treating fluid. A parameter of the formation is monitored to determine whether a formation system strain is within a range. When the formation system strain is out of the range, the flow of the flow constraint material is adjusted. The flow constraint material partially constrains the treating fluid from entering a fracture so as to at least partially redistribute the treating fluid to an another fracture or fractures.

Abstract: An adjustable fracturing system is provided. The system includes an adjustment joint configured to be varied in length to facilitate coupling of a fracturing manifold to a fracturing tree. In one embodiment, the system may also include the fracturing manifold and the fracturing tree. Additional systems, devices, and methods are also disclosed.

Abstract: Well completion technology is disclosed for accounting for fracture surface roughness. A frack fluid is pumped into the wellbore to form a fracture in a formation surrounding a wellbore. In one example, a method for completing a wellbore comprises determining a fracture surface roughness for a given formation rock, and for a give fracture fluid or pumping schedule or both, prior to hydraulic fracturing. A fracture fluid and/or a pumping schedule is selected based on the determined fracture surface roughness and formation characteristics. The selected fracture fluid is pumped into the wellbore, with the selected pumping schedule, to create a desired fracture network in the formation.

Abstract: Systems and methods for the use of traceable metal-organic frameworks in subterranean formations are provided. In one embodiment, the methods comprise: introducing a fluid into a wellbore penetrating at least a portion of a subterranean formation, the fluid comprising a base fluid and a solid particle comprising a metal-organic framework comprising at least one detectable component, wherein the metal-organic framework further comprises at least one metal ion and an organic ligand that is at least bidentate and that is bonded to the metal ion; and detecting one or more signals from the at least one detectable component.

Abstract: Well completion technology is disclosed for resisting imbibing frack fluid into an inner surface of a frack. A frack fluid is pumped into the wellbore to form a fracture in a formation surrounding a wellbore. In one example, formation of transverse micro-fractures extending transverse to the fracture is resisted to resist absorption of the frack fluid into the formation through the inner face of the fracture, and into the transverse micro-fractures formed by the pumping of the frack fluid. In another example, a sealer is added to a frack fluid to sealing or coating an inner face of the fracture with the sealer. In another example, micro-particles with a size less than 100 microns are added to the frack fluid.

Abstract: The system and method for processing flowback fluid include a plurality of wellheads producing flowback fluid flows, a plurality of first stage separators corresponding to at least one wellhead of an installation with multiple wellheads and multiple flowback fluid flows, a plurality of metering devices corresponding to each first stage separator, and a second stage separator in fluid connection with the metering devices and the first stage separators. Flowback fluid flows pass from the wellhead to the first stage separators for initial separation of a gas phase, through the metering devices for determination of production levels for each wellhead, and into the second stage separator for an additional gas phase separation. The storage volumes of the first and second stage separators control the retention time in the second stage separator for safe and efficient operation.

Abstract: The system and method for processing flowback fluid include a plurality of wellheads producing flowback fluid flows, a plurality of first stage separators corresponding to at least one wellhead of an installation with multiple wellheads and multiple flowback fluid flows, a plurality of metering devices corresponding to each first stage separator, and a second stage separator in fluid connection with the metering devices and the first stage separators. The second stage separator includes a solids separator to further control the storage volumes of the first and second stage separators and retention time in the second stage separator by removing solids.

Abstract: Methods and apparatuses for controlling a trajectory of a borehole being drilled into the earth are provided. The apparatus includes a drilling system including a drill tubular, a disintegrating device, and a steering system coupled to the drill tubular configured to steer the drilling system, the drilling system configured to drill the borehole by receiving control outputs from at least one control unit for controlling parameters of the drilling system, the at least one control unit configured to provide the control outputs to the steering system, the at least one control unit being configured to provide depth-based control.

Abstract: An apparatus is for detecting corrosion in an internal pipe bore in a pipeline. A tracer chamber containing a first tracer is formed in a portion of the pipeline and is bounded towards the internal pipe bore by a chamber wall having a first corrosion resistance and including at least one wall portion with a second corrosion resistance, the second corrosion resistance being smaller than the first corrosion resistance. A method is for detecting corrosion in an internal pipe bore in a pipeline.

Abstract: A downhole installation comprises: a first pipe layer 8, a second pipe layer 10 about the first pipe layer 8, an annulus 12 between the first pipe layer 8 and the second pipe layer, and a geological formation outside of the second pipe layer 10.

Abstract: Methods, apparatuses, and computer readable medium including computer program products, are provided for determining the depth of water in a well. A method may include coupling a signal onto a cable connected to a submersible well pump. The method may further include monitoring the cable to determine a first time corresponding to a first reflection of the signal caused by the cable entering a water column between a water surface and the submersible pump. The method may further include monitoring the cable to determine a second time corresponding to a second reflection of the signal caused by an impedance mismatch between the cable surrounded by water and a motor in the submersible well pump. The method may further include determining a water height between the submersible pump and the water surface from the first time and the second time.

Abstract: A tool for detecting a structure in a well includes a receiver coil having a first winding and a second winding, a first circuit to apply an input signal to the second winding, and a detection circuit to detect a response of the first winding to the input signal applied to the second winding. The response of the first winding indicates presence of the structure in the well if the receiver coil is positioned proximate the structure. The depths (or locations) of these structures are used to avoid placing receivers near these structures for EM induction surveys, such as cross-well, surface-to-wellbore, or single-wellbore induction loggings with receivers in metallic casing.

Abstract: A multiple parameter sensing leak detection system may include one or more multi-parameter sensing modules capable of simultaneously measuring downhole temperature, pressure, and acoustic signals. The temperature and pressure detectors may include quartz based sensing elements, and the acoustic detector may include piezoelectric based sensing elements. In one or more embodiments, a plurality of sensing modules may be carried on a caliper for allowing radial identification of leak location. In one or more embodiments, multiple calipers, each carrying a circumferential arrangement of sensing modules may be used to identify annular or inter-annular leakage beyond production tubing using triangulation techniques. A leak analysis method identifies if relative pressure and temperature variation amplitudes fall outside leak thresholds and if power spectral density from noise has anomalous frequency signatures.

Abstract: In some embodiments, an apparatus and a system, as well as a method and article, may operate to substantially simultaneously measure acoustic radiation from a source in a geological formation, at each of at least two sensors in an array, over a selected time period to provide acoustic pressure measurements. Further activity may comprise locating the source at a location in the geological formation with respect to the sensors by determining acoustic intensity associated with the source, based on the acoustic pressure measurements, independent of medium sound velocity in one or more media disposed between the sensors and the source. Additional apparatus, systems, and methods are disclosed.

Abstract: A method of treating a multi-zoned subterranean formation with composites having well treatment agents is disclosed. The well treatment agent treated in each zone is distinguishable. At least a portion of the well treatment agent is released from one of the composites into the well or formation. The formation of undesirable contaminants may be inhibited or prevented in the well or in the formation by the release of the well treatment agent from one or more of the composites. The well treatment agent also serves as a tracer. When fluid transported from the formation or well is collected, the source of the transported fluid may be determined by comparing a chemical or physical parameter of the well treatment agent with a working set of known taggants.

Abstract: An apparatus for remote actuation of a downhole device in a wellbore, that includes a cable head configured to connect with a cable in communication with surface equipment. The cable head is connected with a tractor module. A communication module is connected with the tractor, and a release device is connected with the communication module. The release device is connected with an anchor. The anchor section is connected with a downhole device. The downhole device is configured to communication with the communication module when the communication module is released from the release device.

Abstract: A method for encoding signals using frequency sweeps in a downhole environment, in some embodiments, comprises: obtaining a digital signal; encoding the digital signal using one or more frequency sweeps to produce an encoded signal; transmitting the encoded signal from a transmitter to a receiver, at least one of the transmitter or receiver disposed downhole; receiving the encoded signal at the receiver; and decoding the encoded signal at the receiver to produce a decoded digital signal.

Abstract: A system that is positionable in a wellbore can include a transceiver that is positionable external to a casing string and programmable to vary a number of data packets that are wirelessly transmitted by the transceiver. The number of data packets can correspond to an amount of data wirelessly transmitted by the transceiver about an environment in the wellbore.

Abstract: A system that is positionable in a wellbore can include a transceiver that is positionable external to a casing string. The transceiver can be remotely programmable while in the wellbore to set an internal clock using a timing signal wirelessly transmitted from a source and a position of the transceiver in the wellbore relative to the source. The transceiver can use the internal clock for controlling a timing of the transceiver for transmitting a wireless signal.

Abstract: A data logger comprises a mainboard and a jacketing, wherein the mainboard is covered with the jacketing, wherein the data logger is capable to be carried by said drilling fluid traveled in borehole, wherein the data in borehole is collected by the mainboard of the data logger during traveling.

Abstract: Movable transducer designs used in downhole environments increase the efficiency of the transmitter and receivers, thereby obtaining improved logging data. In one embodiment, the transmitter/receivers are tilted/rotated to direct the strongest acoustic wave pressure to the critical path for increasing signal strength. In other embodiments, the transmitter/receiver may be extended outwardly toward the formation, or retracted inwardly from the formation. An adaptive algorithm is provided to rotate the transmitter/receiver to match the critical angle when the formation slowness changes. Also, a transmitter/receiver port may be designed to have a cone-shape that matches the impedance of the acoustic wave to the surrounding environment.

Abstract: A method including receiving a waveform, identifying the presence of a pulse in the waveform, and subtracting a reflection template from the received waveform when a pulse is present in the waveform to obtain a corrected waveform, is presented. The method may further include reading the corrected waveform using a digital processing protocol and adjusting a drilling parameter according to the reading. A device configured to perform a method as above is also provided. A method as above, further including modifying a drilling parameter in a wellbore based on the reading of a pulse sequence including the waveform is also provided.

Abstract: A method of mapping micro-fractures of a fracture network comprising: introducing a capsule or coated capsule or containment into the fracture network, where in the capsules or containment comprise an explosive substance and a plurality of micro-proppant; allowing initiation of the explosive substance of some or all of the plurality of the capsules to occur, wherein initiation of the explosive substance causes detonation of the explosive substance, and wherein the detonation produces one or more micro-seismic events; and causing or allowing at least a portion of the micro-proppant to enter one or more of the micro-fractures.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to generate a parent population, wherein each member of the parent population includes a set of model parameters describing a layer model of the geological formation; to execute a perturbation algorithm to generate subsequent child populations, from the parent population, until a termination criterion is met; to provide a plurality of solutions based on at least one member of the parent population and on at least one member of each child population; and to control a drilling operation based on a revised layer model that has been generated based on a selected one of the plurality of solutions. Additional apparatus, systems, and methods are disclosed.

Abstract: A cutting tool holding device for holding a cutting tool is provided. The cutting tool holding device includes a base, a holder, and a fastening member. The base includes an embedding portion, an arc receiving hole, and a positioning hole. The holder includes a main body, an arc receiving post, and a guiding block. The main body includes an embedding concave which is detachably embedded with the embedding portion. The arc receiving post is correspondingly set into the arc receiving hole for stably assembled, and the scrap will be guided and discharged through the guiding block.

Abstract: The present invention concerns an air motor comprising a piston and a housing, the piston being received in the housing and dividing the housing into two primary chambers of variable volume. Said motor comprises a first direct supply valve for supplying a first primary chamber of the two primary chambers and a second direct supply valve for supplying the other primary chamber, said two valves each being movable relative to at least one respective seat. The first valve and the second valve are mounted on a same stem movable relative to the housing in a direction parallel to the direction of movement of the piston, and the stem is configured to be moved between a first position and a second position by moving means activated by the piston.

Abstract: The subject matter of this specification can be embodied in, among other things, a method for operating a hydraulic free piston engine includes receiving, at an engine controller for a hydraulic free piston engine, an energy parameter that is representative of an amount of fluid energy to be output by the engine, and a measured fluid pressure value of a fluid load of the engine, determining a piston trajectory of a piston within a hydraulic chamber of the engine, determining a fuel volume value and a servo valve actuation parameter, based on the energy parameter and the measured fluid pressure value, providing a fuel control signal to a fuel control device of the engine based on the fuel volume value, and providing, based on the servo valve actuation parameter and the piston trajectory, a servo valve control signal to a servo valve.

Abstract: A compressed fluid motor comprising at least one solenoid valve, motor timing sensor, and controller for operating the motor.

Abstract: There is provided a free rotary fluid machine including: a main body which is provided in a hollow cylindrical shape, and has an elliptical inner circumferential surface; a rotor which is provided in the main body, and rotates about the same rotation center as the main body; tip seals which are provided at one side of the rotor so as to be in contact with the inner circumferential surface of the main body; and blades which are provided between the tip seals provided adjacent to each other, and supported by the tip seals, in which the blade has one end surface that faces the inner circumferential surface of the main body, and the other end surface that is opposite to one end surface, and centers of radii of curvature of one end surface and the other end surface are positioned at the same side.

Abstract: An optimized mechanical expander or fluid expansion device with a delayed opening timing is disclosed. In the optimized design, rotors in the expander alternatingly rotate sequentially through an intake position in which the transport volume is open to the housing inlet, a closed position in which the transport volume is closed to the housing outlet, and a discharge position in which the transport volume is open to the housing outlet. During rotation, a first opening forms between the housing and each rotor. After further rotation, a second opening is formed that is located between the first opening and a back end of the rotor. In one aspect, the mechanical expander has an opening profile including an initial opening phase in which the opening between the rotor and outlet forms at a lesser rate than during a subsequent secondary opening phase.

Abstract: The turbomachine comprises a casing (26), there being arranged in the casing an impeller (23) arranged on a driven shaft. The turbomachine has an inflow region (21) and an outflow region (22) and, in operation, is flowed through by a working medium. The working medium flows into the inflow region, along a front side (23a) formed on the impeller and subsequently out of the outflow region, there being a pressure drop at the front side between the inflow region and the outflow region. A pressure divider (9) is arranged on the rear side of the impeller, opposite the front side.

Abstract: A gas turbine engine and system for measuring torque for a gas turbine engine shaft is provided. The system may include a first sensor module, a second sensor module, a first coupler, a second coupler, and a static antenna. The first and second sensor modules may include strain sensors positioned on the gas turbine engine shaft. The first coupler may be positioned on the gas turbine engine shaft and electrically connected with the first sensor module. The second coupler may be positioned on the gas turbine engine shaft and electrically connected with the second sensor module. The static antenna may include a first band and a second band. The first signal band may be in operable communication with the first sensor module and positioned radially outward from the first coupler. The second signal band may be in operable communication with the second sensor module and positioned radially outward from the second coupler.

Abstract: An energy conversion device is disclosed. Some embodiments include a mounting system for mounting the device in a fluid, an axle fixed to the mounting system, a hollow shell that rotates about the axle having axial symmetry about a longitudinal axis. The hollow shell may be substantially rounded at the front, expanding to a maximum diameter less than half the distance from the front end to the back end, and tapering radially along the longitudinal axis to the back end. The energy device may further comprise a plurality of blades on the exterior of the hollow shell, each blade extending from the front end of the hollow shell to the back end, rising to a maximum height, and having concave and convex walls. Other embodiments are described and claimed.

Abstract: A gas turbine engine blade includes a blade portion having a leading edge and a trailing edge. A first surface connects the leading edge to the trailing edge and a second surface connects the leading edge to the trailing edge. A tip section is located at a first end of the blade portion and includes a pocket protruding into the tip section from an outermost end of the tip section. The pocket has a first side wall adjacent the first surface and a second side wall adjacent the second surface. At least one of the first side wall and the second side wall have a curve distinct from a curve of the corresponding adjacent surface.

Abstract: A turbine component includes a root and an airfoil extending from the root to a tip opposite the root. The airfoil forms a leading edge and a trailing edge portion extending to a trailing edge. A plurality of axial cooling channels in the trailing edge portion of the airfoil are arranged to permit axial flow of a cooling fluid from an interior of the turbine component at the trailing edge portion to an exterior of the turbine component at the trailing edge portion. A method of making a turbine component includes forming an airfoil having a trailing edge portion with axial cooling channels. The axial cooling channels are arranged to permit axial flow of a cooling fluid from an interior to an exterior of the turbine component at the trailing edge portion. A method of cooling a turbine component is also disclosed.

Abstract: A film-cooled gas turbine component for a gas turbine has a surface exposed to a hot gas and a number of film-cooling openings open out, which film-cooling openings combined to form at least one row transverse to a flow direction of the hot gas. Each of the film-cooling openings has a duct section and a diffuser section having an upstream diffuser edge, two diffuser longitudinal edges and a downstream diffuser edge. At least two immediately adjacent film-cooling openings, of the respective row have their duct axes of the respective duct sections laterally inclined relative to the local flow direction of the hot gas and their diffuser sections are formed asymmetrically with respect to a projection of the duct axis, such that immediately adjacent corner regions of the respective film-cooling openings are in alignment without the respective diffuser sections making contact with one another.

Abstract: The present disclosure is directed to a nozzle cooling system for a gas turbine engine. An impingement plate is positioned radially inwardly from a radially inner surface of an inner side wall of a nozzle. The impingement plate and the inner side wall collectively define an inner chamber. The impingement plate includes a first portion defining one or more impingement apertures and a second portion defining one or more post-impingement apertures. A duct plate encloses the first portion of the impingement plate. The duct plate, the first portion of the impingement plate, and inner side wall collectively define an outer chamber in fluid communication with the inner chamber through the one or more impingement apertures. Compressed air from the outer chamber flows through the one or more impingement apertures into the inner chamber and exits the inner chamber through the one or more post-impingement apertures.

Abstract: A turbine component includes a root and an airfoil extending from the root to a tip opposite the root. The airfoil forms a leading edge and a trailing edge portion extending to a trailing edge. A plurality of nested cooling channels in the trailing edge portion of the airfoil permit passage of a cooling fluid from an interior of the turbine component to an exterior of the turbine component at the trailing edge portion. A method of making a turbine component includes forming an airfoil having a leading edge, a trailing edge portion extending to a trailing edge, and a plurality of nested cooling channels in the trailing edge portion. Each nested cooling channel fluidly connects an interior of the turbine component with an exterior of the turbine component at the trailing edge portion. A method of cooling a turbine component is also disclosed.

Abstract: A turbine component includes a root and an airfoil extending from the root to a tip opposite the root. The airfoil forms a leading edge and a trailing edge portion extending to a trailing edge. Radial cooling channels in the trailing edge portion of the airfoil permit radial flow of a cooling fluid through the trailing edge portion. Each radial cooling channel has a first end at a lower surface at a root edge of the trailing edge portion or at an upper surface at a tip edge of the trailing edge portion and a second end opposite the first end at the lower surface or the upper surface. A method of making a turbine component and a method of cooling a turbine component are also disclosed.

Abstract: A coating system for a surface of a superalloy component is provided. The coating system includes a MCrAlY coating on the surface of the superalloy component, where M is Ni, Fe, Co, or a combination thereof. The MCrAlY coating generally has a higher chromium content than the superalloy component. The MCrAlY coating also includes a platinum-group metal aluminide diffusion layer. The MCrAlY coating includes Re, Ta, or a mixture thereof. Methods are also provided for forming a coating system on a surface of a superalloy component.

Abstract: A method for mounting rotor blades on a rotor disk along a predetermined pitch circle diameter in such a way that adjacent rotor blades, when properly mounted on the rotor disk and in the cold state, are clamped against each other with a predetermined preload. A clamping device which performs such a method has a plurality of clamping elements which are arranged in a uniformly distributed manner around a central axis, the number of which corresponds to the number of rotor blades to be mounted on the rotor disk and which in each case are designed for the locating of a rotor blade, wherein the clamping elements are moveable radially, exerting a radially inwardly directed force.

Abstract: This disclosure provides systems and methods for sealing flow path components, such as turbomachine airfoils, with a front-leaded seal. A seal channel is defined between a portion of the suction side surface of a first flow path component and a portion of the pressure side of a second flow path component. A seal is retained within the seal channel formed by the pressure side portion and the suction side portion and the seal channel defines a forward opening through which the seal is inserted during installation.

Abstract: A nozzle structure is provided between a rotor configured to rotate about an axis and a casing configured to surround the rotor from an outer peripheral side thereof. The nozzle structure includes an outer ring disposed inside the casing; a nozzle provided at an inner radial side of the outer ring; a labyrinth seal including a plurality of fins arranged in a direction of the axis and provided between an inner peripheral surface of the nozzle and an outer peripheral surface of the rotor; and an elastic member provided between the nozzle and the labyrinth seal.

Abstract: A seal ring includes a disk having a radially outer end and an orifice at a center forming a radially inner end, a plurality of holes extending through the disk, and a rail having an annular shape extending axially away from the disk at a position that is between the radially outer end and the plurality of holes extending through the disk with the rail being configured to direct the flow of fluid.

Abstract: A metal gasket bellows seal includes a first ply and a second ply coupled to the first ply at a first location via spot joining at one or more locations.