Abstract: An assembly includes a ported component that includes a bore, radial passages, and axial passages; and a shifting sleeve that comprises a bore, radial passages, seal bosses and associated seal elements that define at least one sealed region with respect to the radial passages of the ported component and that define an open region with respect to the radial passages of the ported component.

Abstract: An apparatus, method, and system for inserting and securing a high pressure transition tube of a fluid transfer tool assembly into a positive position whereby the seal element is packed off in the wellhead set point. Once attached the transition tube is pushed to contact the bit guide, secondary seal or bore machine prep. A lower nose compression seal is seated against transition tube and compressed using an energizer seal to isolate and protect lower pressure wellhead and well control equipment from the higher rated frack pressures or pushing the transition tube and lower nose isolation compression seal to contact the bit guide, secondary seal or bore prep. Pressure is applied to push a seal against the lower and upper compression ring locking them in place preventing movement to form a compression seal and isolating the high pressure passing through the transition tube protecting the wellhead assembly and well control equipment.

Abstract: An apparatus and related method of assembling a degradable plug adapted to selectively permit fluid communication through a flow path of a downhole tubular. In an exemplary embodiment, the method includes providing a housing defining an internal flow passage and one or more internal annular grooves adjoining the internal flow passage; positioning a generally cylindrical core within the internal flow passage; applying a first axially compressive force against the core so that respective exterior portions of the core expand or flow into the one or more internal annular grooves of the housing and the housing elastically deforms in a radially outward direction; and removing the first axially compressive force from the core so that the housing recoils in a radially inward direction, which is opposite the radially outward direction, thus placing a first stress on the core.

Abstract: A subsurface safety valve system for a wellbore is described. The system can include a tubular housing disposed within the wellbore having a cavity running in a longitudinal direction therethrough. The system can also include an electromagnetic device configured to receive electric power to create a magnetic field, and a flapper operative to open and close the cavity in response to the electric power received by the electromagnetic device. The flapper may open in response to the electric power exceeding a first electric power value and remain open in response to the electric power exceeding a second electric power value which is lower than the first electric power value.

Abstract: A downhole tool comprises a housing defining a flow path therethrough in an axial direction from an upper opening to a lower opening. A poppet valve is mounted within the housing. The poppet valve includes an upper member defining an upper chamber mounted in the flow path so that flow through the flow path flows around the upper member, and a valve seat mounted in the flow path with an opening therethrough. A valve poppet is mounted for longitudinal movement within the flow path between a closed position in which the valve poppet seats against the valve seat to block flow through the flow path and an open position in which the valve poppet is spaced apart from the valve seat to permit flow through the flow path. This can restrict/mitigate sand fall-back, e.g., with flow paths designed to prevent/mitigate sand fall-back and for protection of the poppet from sand/debris.

Abstract: Systems and methods describe to a frac sleeve with an expandable ball seat. More specifically, the systems and methods include a sliding frac sleeve with a moving screen, check valve or flapper, wherein the screen, check valve or flapper is configured to align with a fixed production port positioned on an outersidewall.

Abstract: A method to manipulate a well comprising providing an apparatus (60) in a well (14) below a packer (22) or other annular sealing device, the apparatus comprising a container (68) having a volume of gas which is sealed at the surface and nm into the well, such that the pressure in the container (68) is at a lower pressure than the surrounding well. When the apparatus is below the packer, a wireless control signal, is sent to operate a valve assembly (62) to selectively allow fluid to enter the container whereby at least 50 litres of fluid is drawn into the container. In this way, the apparatus can be used independent of perforating guns, to clear perforations or other areas in the well or may be used for a variety of tests such as an interval test, drawdown test or a connectivity test such as a pulse or interference test.

Abstract: A receptacle is formed with a bottom end and a top end and houses an auger conveyor. The system includes at least one bottom sub comprising an inlet end and an outlet end. The outlet end is releasably connectable to a receptacle bottom end. At least one top assembly, comprising a house with an entrance releasably connectable to the receptacle top end and an outlet for connection to an outlet line, and a chamber within the house. The chamber forms a flow path between the entrance and the outlet. A retention tank is connected to the at least one top assembly outlet by the outlet line. A pump is connected to the retention tank on a pump suction side by a supply line, and the pump on the pressure side being connected to the at least one bottom sub by an inlet line.

Abstract: The invention relates to the field of oil and gas production. A perforating gun comprises a single-piece housing containing cavities perpendicular to its longitudinal axis, said cavities being formed directly in the material of the housing of the perforating gun. The following individually manufactured, conjoined structural parts of a shaped charge are hermetically installed directly in the cavities: an outer cap of the shaped charge; a hermetic seal in the form of a ring or gasket; a charge cavity; and a primary explosive pellet. Also disposed in the housing are: a detonation transmission amplifier; a sealing ring; a detonating cord; and a plug with a groove. A detonating cord is connected to each charge, said detonating cord being disposed in a channel formed along the outer surface of the housing and being ballistically connected via an opening to the pellet in the cavity.

Abstract: A bypass plunger includes a unibody, or one-piece hollow body and valve cage, retains a dart valve within the valve cage portion using a threaded retaining nut secured by crimple detents, and includes sealable flow parts. A series of helical grooves surround the central portion of the outer surface of the hollow body of the plunger to control spin during descent. A canted-coil-spring disposed within the retaining nut functions as a clutch. The valve cage includes ports that may be configured to control flow through the plunger during descent. Other embodiments include clutch assemblies using canted-coil springs with split bobbins, and surfaced valve stems surfaced.

Abstract: Disclosed is a system for installing an ESP on a well. In one example the system comprises a production tree (12, 50) that is operatively coupled to a well (14), an ESP spool (16) that is operatively coupled to the production tree and production tubing (60) that extends into the well. The system also comprises an ESP (22) positioned within an inside diameter of the production tubing (60), wherein the ESP (22) comprises an electric motor (22M) and a pump (22P), the electric motor(22M) being positioned above the pump (22P), and wherein the pump (22P) comprises a fluid inlet (22X) and a fluid outlet (22Y). The system is installed above the existing down hole safety valve, and requires no modification to the existing well's completion equipment.

Abstract: Providing pressurized fracturing fluid with a fracturing pump transport comprising a first fracturing pump and a second fracturing pump that are coupled on opposite sides of a dual shaft electric motor. A first drive line assembly comprising a first engagement coupling that allows for selective engagement and/or disengagement of the first fracturing pump with the dual shaft electric motor. A second drive line assembly comprising a second engagement coupling that allows for selective engagement and/or disengagement of the second fracturing pump with the dual shaft electric motor. The fracturing pump transport also comprising an engagement panel that allows for selective engagement or disengagement at the first engagement coupling based on receiving a remote command.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: Provided are methods and systems for monitoring and optimizing stimulation operations in a reservoir. In particular, the methods and systems utilize a downhole telemetry system, such as a network of sensors and downhole wireless communication nodes, to monitor various stimulation operations.

Abstract: A method can include receiving information associated with a conveyance of equipment in a borehole via a cable; determining cable tension values based at least in part on a model and at least a portion of the information; conveying the equipment in the borehole via the cable; acquiring a cable tension value via one or more sensors; comparing the acquired cable tension value to at least one of the determined cable tension values; and, based at least in part on the comparing, setting a cable tension limit for further conveying of the equipment in the borehole via the cable

Abstract: Fracture imaging modules having one or more 3-component sensors, are incorporated into a tool comprising two or more of the modules for detecting microseismic events in a formation from the same wellbore as is being stimulated. The modules are locked together in a compact mode to permit injection into the wellbore through a conventional lubricator which has a fixed length. Once injected into the wellbore, the modules are spaced from one another in an extended mode to form an axially spaced sensor array which increases the measurement window in the wellbore compared to sensor arrays conventionally injected through a fixed length lubricator. Following the operation, the modules are actuated to return to the compact mode for pulling out of the hole through the lubricator.

Abstract: The current subject matter provides a tool and user interface for estimating a velocity at which a plunger of a rod lift pump system will impact a fluid within a well when the rod lift pump system is altered to operate under various conditions of pump fillage. In some embodiments, the estimated impact velocity can be determined using a velocity pattern characterizing a velocity and position of a plunger of a rod lift pump system operating under a condition of complete pump fillage. The estimated impact velocity can provide a user with useful insight into potential operation of the rod lift pump system when operating under various conditions of pump fillage.

Abstract: The present disclosure is directed to an electronic monitoring system having various sensors for monitoring a pumping unit and/or well head. In an embodiment, the system includes a load cell and position sensor that generate dynamometer information. The monitoring system is suited for remote well applications as the system is self-powered (e.g., solar powered) and has wireless communication capabilities allowing remote monitoring in substantially real-time.

Abstract: An apparatus for monitoring rod rotation in a rod lift system. The apparatus comprises one or more sensors that reside on the rod string of the rod lift system. The sensor is configured via a processor to generate a signal indicative of radial position of the sensor relative to an external frame of reference. The signal may be sent to a wireless I/O module, with the signals being indicative of at least partial rotation or, alternatively, a lack of rotation, of the rod-string. The processor is configured to generate an alarm if an absence of rod rotation is detected while the rod lift system is running and transmit this signal to the nearby wireless I/O module. A method for monitoring a reciprocating rod lift system is also provided.

Abstract: A method and electromagnetic ranging system for determining the location of a target well. A method may comprise taking a first measurement with an electromagnetic ranging tool at a first position and calculating a first modeled signal. Additionally, calculating a calibration for the electromagnetic ranging tool from at least the first measurement and the first modeled signal, taking a second measurement with the electromagnetic ranging tool at a second position, and calculating a calibrated measurement. The method may comprise determining a distance, direction, and/or orientation to a target wellbore using at least the calibrated measurement. An electromagnetic ranging system may comprise an electromagnetic ranging tool and an information handling system coupled to the electromagnetic ranging tool.

Abstract: A method includes obtaining a sample of a fluid from a subterranean zone while the fluid is being extracted from the zone. A chemical composition of the sample is measured. A temperature and a pressure of the subterranean zone are measured. The measured properties are associated with a time point. The measured properties are incorporated into a set of historical data. A chemical composition of a fluid to be extracted from the subterranean zone at a future time point is determined based on the set of historical data. A presence of a liquid phase in the fluid to be extracted from the subterranean zone at the future time point is determined. A flow rate of the fluid being extracted from the subterranean zone is adjusted in response to determining the presence of the liquid phase in the fluid to be extracted from the subterranean zone at the future time point.

Abstract: Apparatus (100) for use in sensing temperature along a wellbore, comprising: tubing (110) comprising a plurality of temperature sensor modules (120) provided at locations along the inside of the tubing, having electrical properties that vary with temperature; and an electrical network (115) comprising a plurality of wires and said plural temperature sensor modules, wherein the wires and plural temperature sensor modules are configured as a matrix by which the wires comprise a first group of wires and a second, different group of wires and each wire of the first group is electrically connected to each wire of the second group once, by different temperature sensor modules, such that each temperature sensor module can be individually electrically connected by a pair of wires comprising a first wire from the first group and a second wire from the second group.

Abstract: A downhole calliper tool is for measuring distance between the calliper tool and an interface in a well, such as a petroleum well or a geothermal well. The downhole calliper tool has an impulse radar system (of the CTBV-type) with at least one impulse radar unit configured for: a) transmitting electromagnetic pulses with the impulse radar unit in a direction away from the downhole calliper tool, and for b) receiving reflections of said electromagnetic pulses with the impulse radar unit, and for c) analyzing said reflections to determine the distance between the impulse system and the interface. The impulse radar system is designed for carrying out at least one distance determination per second, but preferably at least ten distance determinations per second.

Abstract: A system or apparatus for use in downhole communication or detection comprises a downhole arrangement defining a throughbore and primary and secondary elements. One of the primary and secondary elements is provided on the downhole arrangement and the other of the primary and secondary elements is provided in the throughbore. The primary and secondary elements are configurable for coupling of an electromagnetic field therebetween. The primary or secondary element which is provided in the throughbore may be provided on a tool such as a shifting tool which is deployable through the throughbore. The secondary element may be configured to provide the electromagnetic field coupled between the first and second elements with one or more characteristic features. The system may be configured for use, in particular though not exclusively, for communicating information to and/or from a downhole tool in an oil or gas well.

Abstract: A passive array of acoustic sensors capture acoustic signals produced by sand movement. The array tool is deployed downhole where it passively listens for acoustic energy generated by sand movement in the well. Once acoustic signals are acquired, model-based frameworks are used to extract single and multiple sensor features from the acoustic signals. The extracted features are used as signatures to detect or classify the production of sand.

Abstract: Systems and methods for conducting production logging for a wellbore are described which incorporate production logging sensors into a bottom hole assembly which is run in on coiled tubing. The production logging system may include a tool for also conducting a secondary operation, such as milling, fishing, perforation or clean out.

Abstract: The invention is a method, a system, tools for use by the system, and an interpretation method for injecting and detecting tracers and conducting flow characterizing of a petroleum well. The method describes monitoring of travel time and slip velocity between two/three different phases (oil/water and possibly gas) in the well. The travel time and slip velocity are determined using an injection tool for injection of an over pressurized injection, thus simultaneous injection to all phases, of the partitioning tracers each of which would follow certain phase. The tracers are detected by a tracer detector downstream the injector. The slip velocity is obtained from the difference of travel time of two tracers which partition to two different phases.

Abstract: Methods and systems for conducting downhole operations including collecting downhole dynamic event data using a downhole tool, wherein the downhole dynamic event data is time-domain data, processing the collected downhole dynamic event data using a computing system located downhole to convert the time-domain data into frequency-domain data, and extracting digital filter coefficients from the frequency-domain data.

Abstract: A downhole system has a plurality of telemetry systems and a control system configured to obtain information from one or more sensors and transmit that information on one or more of the plurality of telemetry systems. The configuration of a controller may be changed so as to change which information is transmitted on a given telemetry system and how the information is to be transmitted on the given telemetry system.

Abstract: A transmitter is carried proximate to an inground tool for sensing a plurality of operational parameters relating to the inground tool. The transmitter customizes a data signal to characterize one or more of the operational parameters for transmission from the inground tool based on the operational status of the inground tool. A receiver receives the data signal and recovers the operational parameters. Advanced data protocols are described. Pitch averaging and enhancement of dynamic pitch range for accelerometer readings are described based on monitoring mechanical shock and vibration of the inground tool.

Abstract: Disclosed herein are methods and systems for operating and maintaining downhole wireless networks. The methods and systems utilize a downhole tool, such as a downhole tool comprising a communications device, to perform maintenance on the downhole wireless network, and for overcoming and/or correcting communications errors along the network. The downhole tool may also be used for updating and reprograming communication nodes in the downhole wireless network.

Abstract: Well systems comprise communicating devices for use in subterranean formations. An example well system comprises a mud valve system having a stator and a rotor to modulate drilling mud flow to provide increased pulse amplitude signals up-hole for improved and faster signaling from down-hole tools while also providing for better detection capability up-hole. The improved signaling technique permits for deeper well applications.

Abstract: A method and system are described for creating subsurface models that accounts for pore type influences. The method includes identifying pore types and properties based on pore types, constructing a subsurface model for a subsurface region and using the subsurface model in simulations and in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.

Abstract: The present disclosure relates to an automatic system and method for detecting problematic geological formations ahead of tunnel faces. The automatic system includes a data acquisition module configured to acquire data, a data transmission module configured to transmit the data and a control and data analysis module configured to receive and analyze the data and determine the geological formations ahead of the tunnel faces. The data acquisition module includes at least one three-component detector and a processor. The three-component detector is installed in a borehole in a side wall of the tunnel. The data transmission module includes a synchronous communicator and a signal line with shielding properties. The synchronous communicator is connected with the three-component detector via the signal line. The control and data analysis module includes a host and a control and analysis procedure of the host. The host is connected with the synchronous communicator.

Abstract: Fluid properties like viscosity, yield strength, and density may be measured by analyzing fluid motion in response to disturbing the surface of the fluid. For example, a method may include disturbing a surface of a fluid in one or more locations, thereby forming a deformation and waves at the surface of the fluid for the one or more locations; imaging and measuring at least one selected from the group consisting of the deformation, the waves, and a combination thereof; and calculating a property of the fluid based on the at least one selected from the group consisting of the deformation, the waves, and a combination thereof, the property selected from the group consisting of viscosity, yield strength, density, and any combination thereof.

Abstract: A method of moving waste material from a mining site using at least one excavator and a plurality of dozers, including excavating material with the at least one excavator from a dig area, said at least one excavator moving along an excavator path that is parallel with the dig area, transferring the excavated material to a plurality of slots, each of said slots are positioned at an angle to the excavator path, and pushing the transferred material by one of said plurality of dozers along the slot and away from the excavator path; wherein each slot allows each of the plurality of dozers to move between a proximal position and a distal position relative to the excavator path.

Abstract: A mine roof support comprises two or more frusto-conical, tubular sections, the sections each flared outwardly from an upper end to a lower end thereof, a skirt portion of a section being received and secured within a neck portion of a section below in a frictional fit to define an interior volume of the mine roof support. A solid, compressible, load-bearing material is located within the volume. Methods of installing a mine roof support and a pre-installation assembly for a mine roof support are also disclosed.

Abstract: A polymer sheet adapted to attach to a material body such as a ceiling of a geological cavity and provide protective cover. The sheet comprises: a webbing portion defining a plurality of primary openings; and two margin portions extending along opposite edges of the sheet on either side of the webbing portion along a length of the sheet, each margin portion defining a plurality of secondary openings, wherein the margin portions are angled relative to the webbing portion.

Abstract: A methods and systems for determining a change in condition of a rock bolt. Some methods may comprise, at a first point in time, propagating shear and longitudinal ultrasonic waves along the rock bolt to measure a first time of flight for each of the shear and longitudinal waves, at a second point in time after the first point in time, propagating shear and longitudinal ultrasonic waves along the rock bolt to measure a second time of flight for each of the shear and longitudinal waves, and using the relative changes of the first and second time of flights, determining the change in condition of the rock bolt section.

Abstract: A gas turbine engine includes a combustion section and a compressor section, the compressor section including a high pressure compressor. The high pressure compressor includes an aft-most compressor stage and an upstream compressor stage, each of the aft-most compressor stage and the upstream compressor stage including a rotor disk. The gas turbine engine also includes a high pressure spool assembly, the high pressure spool assembly including a rotor disk, and an airflow member extending from the rotor disk of the high pressure spool assembly to the rotor disk of the upstream compressor stage of the high pressure compressor to define in part a compressor cooling air passage outward of the airflow member along a radial direction.

Abstract: A method for profiling blades of an axial turbomachine includes preparing a geometric model of a blade profile; determining an oscillation mode of the geometric model; calculating a time profile of a position-dependent disruptive pressure in a channel between two adjacent blade profiles over an oscillation period of the oscillation belonging to the oscillation mode, changing the geometric model and determining a different oscillation mode for the modified geometric model; and determining the damping of the oscillation using the disruptive pressure profile calculated previously and accepting the modified geometric model for the case that the damping of the oscillation turns out to be greater than calculated, otherwise repeating the last two steps with another modified geometric model.

Abstract: A vane assembly for a gas turbine engine includes an inner diameter platform, an outer diameter platform, and an airfoil shaped vane spanning from the inner diameter platform to the outer diameter platform. The airfoil shaped vane includes an internal cooling passage having a first inlet at the inner diameter platform and a second inlet at the outer diameter platform. An outer diameter platform cover is disposed radially outward of the outer diameter platform, relative to a radius of an arc defined by an arc of the outer diameter platform. The outer diameter platform includes at least one coolant cover inlet hole, the at least one coolant cover inlet hole being aligned with a corresponding second inlet.

Abstract: Thermal barrier coatings, which may be used in gas turbine engines, comprise or consist of a tantala-niobia-zirconia mixture that is stabilized with two or more stabilizers. An exemplary thermal barrier coating comprises or consists of, by mole percent: about 2% to about 30% YO1.5; about 8% to about 30% YbO1.5 or GdO1.5 or combination thereof; about 6% to about 30% TaO2.5; about 0.1% to about 10% NbO2.5; about 0% to about 10% HfO2; and a balance of ZrO2.

Abstract: A staking tool assembly for staking a pin coupling a turbine blade with a turbine disk is disclosed. The staking tool assembly includes a guide block configured to be positioned between a space defined between two consecutive turbine blades mounted on the turbine disk. The guide block includes a bottom surface configured to abut a blade root of the turbine blade. The guide block further includes a groove extending from the bottom surface through the guide block. The groove is configured to receive a portion of the pin extending outwardly from the blade root to facilitate a staking of the pin.

Abstract: Assembly (2) comprising an annular turbine distributor (3) for turbomachinery (1), an annular structural element (4) of the turbomachinery (1), coaxial with the distributor (3) and at least one device (5) for attaching the annular distributor (3) with the annular structural element (4), characterised in that: —the annular distributor (3) is crossed by at least two axial passages, and —the or each attachment device (5) comprises: at least two pins (15), rigidly connected to the annular structural element (4) and passing through one of said passages of the distributor (3), a first transverse stop (16) for stopping the distributor (3) axially and passing through two consecutive pins (15), and two second stops (17) rigidly connected to the structural element (4) to retain, in the pins (15), the first transverse stop (16) for stopping the distributor (3) radially.

Abstract: An assembly for a turbomachine and a method for assembling a plurality of flow path components are presented. The assembly includes a plurality of flow path components disposed adjacent to one another, each flow path component having a forward surface, an aft surface, a pressure side surface, and a suction side surface. A seal channel is defined by the pressure side surface and the suction side surface of adjacent flow path components. The seal channel has an open forward end proximate to the forward surfaces and at least two rear ends proximate to the aft surfaces. The assembly includes a plurality of seal layers disposed within the seal channel such that one or more seal layers extend from the open forward end to a rear end and one or more other seal layers extend from the open forward end to another rear end.

Abstract: A leaf seal assembly 10? is disclosed for use in a gap between a rotating component 1 and a stationary component 2, for example of a turbo-machine. The leaf seal assembly 10 comprises at least one leaf seal 20 having a generally planar surface. A runner 50? is coupled to a distal end of the least one leaf seal 20. The at least one leaf seal 20 maintains the runner 50? in a first position away from the rotating component 1 in an unpressurised inoperative state. The runner 50 moves to a second position, close to, but not contacting, the rotating component 1 in a pressurised operative state. In some embodiments the at least one leaf seal is angled in the direction of the flow. In some embodiments a first leaf seal is vented. In some embodiments the leaf seal assembly is segmented.

Abstract: A connection valve for a multi-flow turbine of an exhaust gas turbocharger and/or a turbine with such a connection valve. The connection valve has a housing and a valve body. The valve body is arranged in the housing to be displaceable along a first axis. The valve body has a closure part which is designed to close a connection opening between a first volute and a second volute of the multi-flow turbine.

Abstract: This application provides a steam turbine. The steam turbine may include a number of controlled flow runners and a number of controlled flow guides. The controlled flow guides may include an upstream passage ratio (Wup/W) of 0.4 to 0.7.

Abstract: A turbine system includes a foam generating assembly having an in situ foam generating device at least partially positioned within the fluid passageway of the turbine engine, such that the in situ foam generating device is configured to generate foam within the fluid passageway of the turbine engine.