Abstract: A sand control screen assembly includes a base pipe and a sand screen positioned about an outer surface of the base pipe. An annular flow ring is positioned about the outer surface of the base pipe and is operatively coupled to the sand screen. The annular flow ring includes a cylindrical outer sleeve, a cylindrical inner sleeve received within and coupled to the outer sleeve, and a plurality of radial projections extending radially inward from the inner sleeve to radially support the annular flow ring against the outer surface of the base pipe. A flow annulus is defined between the outer surface of the base pipe and the annular flow ring and the sand screen, and the plurality of radial projections extends into the flow annulus.

Abstract: A downhole sand control completion system includes a completion string extendable within a wellbore and including one or more sand control screen assemblies arranged about a base pipe, each sand control screen assembly including one or more sand screens positioned about the base pipe. A shunt system is positioned about an exterior of the base pipe to receive and redirect a gravel slurry flowing in an annulus defined between the completion string and a wellbore wall. A return tube is positioned about the exterior of the base pipe and extends longitudinally along a portion of the completion string. The return tube defines a plurality of openings to receive a portion of a fluid in the annulus into the return tube to be conveyed into an interior of the base pipe via the return tube.

Abstract: Provided is an improved bypass durable dart plunger that descends faster in a hydrocarbon well, is capable of lifting more fluids and has a durable and replaceable clutch assembly. The various components of the durable dart plunger includes a sleeve, a dart body with a one or more flow ports (chokes) cut at right angles through the dart body, a pin and a replaceable clutch assembly (also referred to a retention assembly). The chokes can be of varying sizes. In one embodiment, the clutch assembly includes a plurality of clutch mechanisms wherein each mechanism includes a ball, a socket screw and a resilient spacer.

Abstract: A device is taught for pumping fluid from a downhole reservoir up to surface. The device comprises a conduit extending through at least a portion an axial bore of the rotor unit and in communication with one or more recirculation inlets for receiving a recirculation stream of fluid and directing under pressure through the conduit, wherein an inside diameter and length of the conduit define a flow restriction; and one or more recirculation outlets defined in a stator unit downstream of the pump fluid intake, for delivering the recirculation stream of the fluid under pressure from the conduit and directing it at the pump fluid intake. A method is also taught for washing particulate from an intake end of a pump.

Abstract: The invention relates to a system and method for steam assisted gravity drainage of hydrocarbons having increased solvent recovery thus improving the economics of steam-only injection processes such as steam assisted gravity drainage while reducing environmental impact. Embodiments aid the condensation of solvent either by shutting-in or reducing the steam injection or by injecting a secondary lighter and cheaper solvent post solvent-steam co-injection, after which, normal steam injection at optimized operating conditions is restarted and continued until blow down while primary solvent recovery is continued, thus significantly accelerating and maximizing the recovery of solvent injected without affecting the long term cumulative bitumen production.

Abstract: A method and a system for recovering oil from currently inaccessible oil containing geological units by activating the deep biosphere microbial seed bank. Nutrient and thermal enhancement of microorganisms in oil containing geological units allows for stimulation of inactive and/or dormant microorganisms such that they proliferate and produce gas. The oil viscosity that is decreased by heat, along with the gas pressure produced by activated microbes which allows previously inaccessible oil to flow toward production wells.

Abstract: A method of blowdown for a steam chamber of a thermal recovery process is provided. A blowdown mixture is introduced into the steam chamber. The blowdown mixture can include glycol and water. Heat can be adsorbed from the steam chamber onto the blowdown mixture. A viscosifying agent can also be introduced into the steam chamber. Oil from the steam chamber can be emulsified with the viscosifying agent to produce oil or emulsions of oil. The blowdown mixture and the oil or emulstions of oil can both be recovered from the steam chamber.

Abstract: A method for treating a hydrocarbon bearing formation bounded by at least one nonbearing formation comprises inserting a tubular into a wellbore formed in the hydrocarbon bearing formation. The tubular defines proximal and distal ends and further has a sidewall defining inner and outer surfaces and a tubular bore, where an annulus is defined between the outer surface of the sidewall and the inner surface of the wellbore. A detonator is disposed in the annulus through at least a portion of the hydrocarbon bearing formation. A first fluid including a first explosive is pumped through the tubular bore into a selected portion of the annulus. An isolation material is inserted in the annulus between an entrance of the wellbore and the first explosive fluid. The explosive fluid is detonated with the detonator.

Abstract: A fracturing assembly for forming fractures in a subterranean formation includes a source tool having a rotational joint moveable to orient the source tool in a range of directions and a directional electromagnetic antenna having an electromagnetic wave source. A ceramic-containing member is located within a distance of the electromagnetic antenna to be heated to a fracture temperature by electromagnetic waves produced by the electromagnetic wave source. The ceramic-containing member is positionable to orient a fracture in the subterranean formation at the fracture temperature.

Abstract: A method of increasing hydrocarbon production by hydraulic fracturing in shale formations by using an a-seismic process of cyclic injection of cooled aqueous fluid at a low rate with shut-in periods to induce tensile failure in the formation and create a fracture network of high and very high conductivity fractures with sufficient lateral extension in a completed well. A final single cycle of aqueous fluid and proppant is used in which the volume of proppant has been determined from measurements of the downhole pressure. Further fracture parameters being: volume of the very high conductivity fractures, lateral extension of the very high conductivity fractures, surface of the very high conductivity fractures and estimation of the global fracture network shape are determined and analysed after each injection cycle.

Abstract: A method of extracting hydrocarbons from a wellbore formed in a subterranean rock formation. The wellbore includes at least one fracture extending therefrom. The method includes forming a particle-free treatment fluid that includes an uncured, particle-free proppant material, and injecting the particle-free treatment fluid into the wellbore and towards the at least one fracture. The uncured, particle-free proppant material is configured to cure in-situ when positioned within the at least one fracture.

Abstract: A method of processing a fluid produced from a well, the produced fluid being a high pressure fluid, the method comprising: reducing the pressure of the fluid to a reduced pressure such that a gas phase and a liquid phase are formed; separating the gas phase from the liquid phase thus forming a gas product and a liquid product; and storing the liquid product in a storage tank at a pressure such that the liquid product remains in a stable liquid phase during storage, wherein the reduced pressure is greater than atmospheric pressure.

Abstract: An electric submersible pump (ESP) is coupled with a spaced apart debris removal assembly that is independently supported from a retrievable packer. The debris removal assembly is modular and retains the captured debris for subsequent removal from the well with the retrievable packer. The ESP suction draws in well fluids through the debris retention device. The ESP can be pulled to allow removal of the retrievable packer with the debris removal assembly.

Abstract: A weir assembly system comprises an insert dimensioned to be inserted into a section of a wellbore and a plurality of weirs spaced within the insert so as to increase the separation of solids from fluid within the section of the wellbore when the fluid is flowing through the wellbore. The plurality of weirs may be oriented to create a tortuous fluid flow path, such that a flow opening of a first weir causes solids to deposit at a second weir without obstructing a flow opening of the second weir. Additional apparatus, methods, and systems are disclosed.

Abstract: A downhole apparatus comprising a body configured to be coupled to a production tubular and an upper opening and a lower opening. First and second flow paths are provided between the upper opening and the lower opening in the body, and a flow diverter is arranged to direct downward flow through the body towards the second flow path and away from the first flow path. A filter device in the second flow path filters or collects solid particles in the second flow path from passing out of the lower opening of the apparatus. The apparatus has particular application to artificial lift hydrocarbon production systems, and may be installed above a downhole pump in a production tubing to prevent solids from settling on the pump during pump shutdown. Embodiments for use with ESPs and PCPs are described.

Abstract: Methods and systems for automated well event detection and response are provided herein. Example methods are implemented in an automated tripping management application. The application can execute to perform a remote management function for operation of a drilling rig. This includes monitoring actual and calculated running speeds, bottom hole pressures, and drill string pressures based on fluids used at the drilling rig, and generating both alerts in the event of operation outside of predetermined thresholds, and recommended adjustments to operation of one or more drilling rigs. The thresholds and alerting can be based on a set of operating rules developed to automate monitoring of such processes in a way that additional events are detected and responded to.

Abstract: A method of controlling rates of moving a coiled tubing string in a wellbore includes providing an injector head control system for moving a bottom hole assembly at an end of the coiled tubing string in the wellbore, that maintains operating settings of the injector head if the control system determines that the bottom hole assembly is moving in the wellbore within a range of rates, and varies operating settings of the injector head if the control system determines that the bottom hole assembly is moving in the wellbore outside the range of rates, to thereby revert to moving the bottom hole assembly in the wellbore within the range of rates. The control system determines whether the bottom hole assembly is moving within or outside the range of rates based on one or more sources of feedback from both the bottom hole assembly and the injector head.

Abstract: A system for drilling a borehole according to the present invention includes a drill rig and a control system. The drill rig includes a drill, an air injection system and a water injection system. The control system, which is operatively associated with the drill rig, receives information from the drill rig that relates to at least one drill parameter. The control system processes information relating to the drill parameter, determines whether the drill parameter is within a predetermined specification for the monitored drill parameter, chooses a hole defect mitigation routine based on the monitored drill parameter when the monitored drill parameter is outside the predetermined specification, and controls the drill rig to implement the chosen hole defect mitigation routine.

Abstract: A distributed downhole sensor system for a well includes a sensor array comprising. The sensor array includes a plurality of sensors and cable segments. Each sensor is associated with a unique digital address and locatable downhole to capture sensor data simultaneously and output the simultaneously captured sensor data under a first control condition, and a single sensor of the plurality of sensors is configured to capture sensor data independently and output the independently captured sensor data under a second control condition. The cable segments couple the sensors in a line or an array to deliver power to the sensors and provide a communication channel to and from the sensors.

Abstract: A method for making dynamic gravity toolface measurements while rotating a downhole measurement tool in a borehole is disclosed. The method includes processing magnetic field measurements and accelerometer measurements to compute a toolface offset and further processing the toolface offset in combination with a magnetic toolface to obtain the dynamic gravity toolface. Methods for correcting dynamic and static navigational sensor measurements to remove sensor biases, for example, are also disclosed.

Abstract: Electrically-operated downhole tools are run into a wellbore on a coiled tubing string which includes tube-wire that is capable of carrying power and data along its length. During operation, a downhole tool is provided power from surface using the tube-wire. Downhole data is provided to the surface via tube-wire.

Abstract: Systems and methods are provided for estimating the tool center position of a down-hole tool, the geometry of the borehole, and/or a mud parameter based on sensor measurements from the downhole tool, even when the downhole tool center is moving over time. At least one sensor may obtain a set of measurements that relates to distance-to-borehole in a borehole at a number of azimuths. A processor may estimate a set of values defining borehole boundary and a set of positions of a center of the downhole tool in the borehole, at least in part by estimating the borehole boundary based on the set of measurements assuming a previously estimated position of the center of the downhole tool is true and estimating the position of the center of the downhole tool based on the set of measurements assuming a previously estimated borehole boundary is true, and iterating at least until convergence.

Abstract: A device is described for measuring downhole flow rate, density and fluid fractions of oil-gas-water mixtures in a production string.

Abstract: Methods and apparatus for monitoring and controlling wellsite emissions. A mobile emissions monitoring device is operated in airspace above a wellsite to generate and transmit a monitor signal related to emissions in the airspace. The emissions may be associated with wellsite equipment at the wellsite. A processing system in receipt of the monitor signal operates to cause a change in an operational parameter of the wellsite equipment based on information conveyed by the monitor signal.

Abstract: An electromagnetic telemetry system adjusts telemetry parameters which may include carrier frequency, signal amplitude and/or data encoding protocol to achieve reliable data transmission and to conserve power. In some embodiments, sweep signals transmit a range of carrier frequencies and the parameters are determined in part by analyzing the received sweep signals. In some embodiments, different parameters are selected automatically based on a mode of drilling.

Abstract: Methods and devices for imaging wells using phased array ultrasound imaging devices is described. The devices enable high resolution real-time imaging of a well during various operations in the well, including during completions, fracturing, milling, fishing and drilling operations. The phased array ultrasound imaging devices may be integrated with other well tools, such as a bottom hole assembly (BHA), fishing tools, milling tools, fracturing tools, and drilling tools, in order to integrate imaging capabilities into such tools.

Abstract: A hydraulic fracturing system includes a perforating tool configured to perforate a casing of a well and a computing system communicatively coupled to the perforating tool. The computing system is configured to determine a plurality of geomechanical properties associated with a plurality of depths of the well and associated with a subterranean region adjacent to the well based on seismic data representative of the subterranean region; determine stress regime of each of the plurality of depths based on the plurality of geomechanical properties; classify at least one continuous interval of the plurality of depths as a critical net pay (CNP) region based on the stress regime of each depth of the at least one continuous interval; and send a command to the perforating tool to perforate the casing of the well at a depth associated with the CNP region within the at least one continuous interval.

Abstract: Systems, devices, and methods for producing a three-dimensional visualization of one or more of a drilled wellbore, a bottom hole assembly, a drill bit, a drill plan, and one or more lithology windows is provided for drill steering purposes. A drilling motor with a toolface in communication with a sensor system is provided. A controller in communication with the sensor system is operable to generate a depiction of the drill plan, a depiction of the drilling motor, and one or more lithology windows, and to combine these depictions in a three-dimensional visualization of the down hole environment. This visualization may be used by an operator to steer the drilled wellbore.

Abstract: Apparatus, computer readable medium, and program code for identifying rock properties in real-time during drilling, are provided. An example of an embodiment of such an apparatus includes a downhole sensor subassembly connected between a drill bit and a drill string, acoustic sensors operably coupled to a downhole data interface, and a surface computer operably coupled to the downhole data interface.

Abstract: A method for assigning a set of tasks to a plurality of mining machines, said machines being arranged to be driven between positions for performing tasks is provided. The method includes defining a first set of constraints to be fulfilled finding an overall solution fulfilling the first set of constraints by solving each constraint as a sub-problem, a solution to at least one sub-problem being dependent on the solution of at least one other sub-problem; the overall solution fulfilling the first set of constraints being an overall solution where a first of said sub-problems is validated by solutions of others of the sub-problems, and assigning tasks to the machines according to the determined validated overall solution, wherein tasks are arranged to be carried out at least partially overlapping in time by the mining machines.

Abstract: This invention relates to a clamp assembly for clamping an elongate member such as a roof bolt, drill rod and the like, the clamp assembly comprising a housing having a receiving zone/gap for receiving the elongate member; a first jaw and a second jaw accommodated within the housing, wherein at least one of the first and second jaws being moveable within the housing between an opened position for allowing the drill rod to be received through the gap and between the first and second jaws, and a closed position for clamping the drill rod that is received in the gap between the first and second jaws; and an actuator for displacing at least one of the first and second jaws between the opened and closed positions.

Abstract: Disclosed is a steam turbine capable of reducing the load of a bearing supporting a turbine shaft transmitting rotational driving force of a plurality of nozzle-equipped rotary bodies arranged in multiple stages. The steam turbine includes a housing (110); a turbine shaft (120) pivotably supported by a bearing (121) in the housing; and a plurality of dish-shaped nozzle-equipped rotary bodies (130) integrally combined with the turbine shaft (120), provided with one or more nozzle holes (131) from which working fluid is ejected so that the nozzle rotations bodies (130) can be rotated, and stacked in an axial direction of the turbine shaft (120). The nozzle hole (131) is inclined with respect to a normal direction n of the periphery surface of the nozzle-equipped rotary body (130) and is inclined toward an axial direction c of the turbine shaft (120).

Abstract: A shear flow turbomachinery device includes a housing having housing walls defining a cavity, a shaft extending into the cavity though a shaft opening in the housing wall at an end of the cavity, a for coupled to the shaft within the cavity, the rotor having a plurality of disks extending radially outward from a central axis of the rotor, the disks having a spaced arrangement forming a gap between adjacent disks, and a shroud for shrouding the rotor, the shroud including a pair of end disks coupled to opposing ends of the rotor, a screen extending between outer edges of the pair of end disks, the screen extending around the rotor between the rotor and the housing walls, wherein the shroud is freely rotatable independent of rotation of the rotor to reduce drag on the disks due to the housing walls when the cavity if filled with fluid and the shaft and plurality of disks are rotated.

Abstract: Provided herein is a rotor attachment assembly for an aircraft. A rotor attachment assembly includes a connecting assembly associated with the aircraft and a rotor assembly configured to be connected to the connecting assembly. The rotor assembly includes a plurality of fins configured to fit a respective plurality of cut-outs of the connecting assembly, a hollow section configured to accommodate at least a part of a pin of the connecting assembly so as to center the rotor assembly relative to the connecting assembly, and a spring configured to expand to allow the fins to pass and to close to retain the fins when the rotor assembly is connected to the connecting assembly.

Abstract: A turbine wheel for a turbine of an exhaust gas turbocharger includes at least one turbine blade against which exhaust gas can flow. The maximum ratio of the wheel outlet diameter of the turbine wheel to the thickness of the turbine blade is 111.75.

Abstract: An actively cooled component can be an airfoil, such as an air foil in a jet turbine engine. The component may have a body comprising at least one internal channel adapted for a flow of a cooling media therein. The channel may have two side walls separating a cold inner surface and a hot inner surface. The cold inner surface may have two impingement holes in fluid communication with a cooling media source, allowing for ingress of the cooling media into the internal channel. The hot inner surface may have one angled film hole in fluid communication with a hot outer surface, allowing for egress of the cooling media out of the internal channel. The first and second side walls may enclose a length of the internal channel along which the angled film hole is located between the two impingement holes.

Abstract: A trailing edge cooling feature for a turbine airfoil (10) includes a plurality of pins (22a-l) positioned in an airfoil interior (11) toward the trailing edge 20), each extending from the pressure side (14) to the suction side (16) and further being elongated in a radial direction (R). The pins (22a-l) are arranged in multiple radial rows (A-L) spaced along the chordal axis (30), with the pins (22a-l) in each row (A-L) being interspaced to define coolant passages (24a-l) therebetween. A row of radially spaced apart partition walls (26) are positioned aft of the pins (22a-l). Each partition wall (26) extends from the pressure side (14) to the suction side (16) and is elongated in a generally axial direction, extending along the chordal axis (30) to terminate at the trailing edge (20).

Abstract: A turbine blade according to the invention includes a first wall surface facing a cooling passage through which cooling air flows; a second wall surface facing a working fluid passage through which a working fluid flows; a communication hole establishing communication between the cooling passage and the working fluid passage; and a projection provided on the downstream side of the flowing direction of the cooling air in the opening of the communication hole formed in the first wall surface, the projection protruding from the first wall surface toward the cooling passage. The projection includes a slope section formed on the first wall surface that ascends in the direction opposite the flowing direction of the cooling air toward the cooling passage and a curved section formed as a convex section on the side of the cooling passage, the curved section extending along the opening in the form of an arc.

Abstract: A turbine blade assembly may be provided for use in a gas turbine engine. The turbine blade assembly may include an airfoil and a tip shroud. The airfoil may extend radially outward from an axis of rotation of the airfoil. The tip shroud may be located at a radial end of the airfoil. The tip shroud may include a seal rail that extends in a direction of rotation of the airfoil. A notch, including a Z-notch or a V-notch, may be situated on a first side of the seal rail at an end of the seal rail. A variable fillet may be situated on a second side of the seal rail that is opposite of the first side on which the notch is situated. The variable fillet is a fillet having a curvature that varies along a length of the second side.

Abstract: A part include a refractory alloy including a niobium matrix having metal silicide inclusions present therein, the surface of the part being coated by a protective coating, the protective coating including a phase having the following stoichiometry: (NbxTi1-x)3M?Cr?Si?X? where M designates Fe, Co, or Ni, X designates one or more other elements that might be present, x lies in the range 0 to 1, x lies in the range 5 to 8.5, and the sum ?+? lies in the range 3 to 7; or Nb4M?ƒSi?X??? where M? designates Fe, Co, or Ni, X? designates one or more other elements that might be present, ? lies in the range 3.2 to 4.8, and ? lies in the range 6 to 8.

Abstract: A mower blade lock has a blade hook and a handling portion connected opposite each other along a connecting body.

Abstract: A securing device for a turbine blade wherein the securing device prevents the turbine blade from moving radially and axially and includes a retaining piece that includes a projection which extends into a recess in the root of the turbine blade and which prevents the blade from moving axially.

Abstract: An apparatus for axial locking of a bucket includes a depressed portion formed on an end portion of a male dovetail extending from a bucket and on an outer side of a seating groove of a female dovetail disposed on an outer circumferential surface of a rotor disk, and a locking member disposed in the depressed portion and configured to contact the male dovetail and the seating groove of the female dovetail to prevent the bucket mounted on the rotor disk from being separated in the axial direction.

Abstract: A ceramic brush seal for a gas turbine engine, and a process for manufacturing the seal are provided. In one example, the process includes deinfiltrating an edge of a plurality of plies having a preimpregnated configuration. The edge is defined by a plurality of ceramic fibers extending away from a portion edge of a matrix infiltrated portion of each of the plies. In another example, the process includes masking an edge of a plurality of plies, the edge being defined by a plurality of ceramic fibers extending away from a portion edge of a body portion of each of the plies, and infiltrating the body portion of the plurality of plies with a ceramic matrix slurry. The plies are stacked, formed into a green body and then fired to form the component. The plies may include oxide/oxide woven ceramic fiber plies.

Abstract: Aspects of the disclosure are directed to a seal configured to interface with at least a first component and a second component of a gas turbine engine. A method for forming the seal includes obtaining an ingot of a fine grained, or a coarse grained, or a columnar grained or a single crystal material from a precipitation hardened nickel base superalloy containing at least 40% by volume of the precipitate of the form Ni3(Al, X), where X is a metallic or refractory element, and processing the ingot to generate a sheet of the material, where the sheet has a thickness within a range of 0.010 inches and 0.050 inches inclusive.

Abstract: An air-fire seal designed to be attached to a first tubular member of a turbomachine, such as a bleed duct, and to rest against a second member of the turbomachine, such as an intermediate casing hub, includes an attachment base having an annular shape around a reference axis (Y); a first annular fire-stop lip extending from the attachment base over a first length (L1); and a second annular air-sealing lip extending from the attachment base over a second length (L2) lower than the first length and facing the first lip.

Abstract: Flow path assemblies for gas turbine engines are provided. For example, a flow path assembly comprises an inner wall defining an inner boundary of a flow path and a plurality of pockets therein, and a unitary outer wall defining an outer boundary of the flow path. The unitary outer wall includes combustor and turbine portions that are integrally formed as a single unitary structure. The flow path assembly further comprises a plurality of nozzle airfoils that each have an inner end radially opposite an outer end and define an internal cavity for receipt of a flow of cooling fluid. The inner end of each nozzle airfoil is received in one of the plurality of inner wall pockets and defines an outlet for the flow of cooling fluid to flow from the internal cavity to the pocket, which forms a fluid curtain to discourage fluid leakage from the flow path.

Abstract: A dry gas seal for sealing the shaft of a turbomachinery, provided with means for the continuous health monitoring of the dry gas seal comprising one or more sensors adapted to measure strains and/or loads induced to the primary ring of the dry gas seal and/or strains induced to one or more of the elastic elements coupled to the primary ring and/or adapted to measure displacements of the primary ring or of an element coupled to the primary ring, for an early detection of failure of the seal, thus enabling main failures early detection capability and proactive maintenance actions.

Abstract: A turbine engine according to an example of the present disclosure includes, among other things, a fan shaft, at least one tapered bearing mounted on the fan shaft, the fan shaft including at least one passage extending in a direction having at least a radial component, and adjacent the at least one tapered bearing, a fan mounted for rotation on the at least one tapered bearing. An epicyclic gear train is coupled to drive the fan, the epicyclic gear train including a carrier supporting intermediate gears that mesh with a sun gear, and a ring gear surrounding and meshing with the intermediate gears, wherein the epicyclic gear train defines a gear reduction ratio of greater than or equal to 2.3. A turbine section is coupled to drive the fan through the epicyclic gear train, the turbine section having a fan drive turbine that includes a pressure ratio that is greater than 5. The fan includes a pressure ratio that is less than 1.45, and the fan has a bypass ratio of greater than ten (10).

Abstract: A control ring for a stage of variable-pitch vanes for a turbine engine includes at least one member for bearing on a casing and means for fixing the member. The member includes a bushing with an axial bore for the passage of the member or an element for supporting the member. A through-slot opens into the bore and allows for substantial radial deformation of the bushing. The member further include an outer thread for screwing the bushing into a complementary thread of a hole in the body, thereby deforming the bushing. The member or support can be mounted and moved inside the bore, to a second position, in which the bushing is radially constrained and is tightly mounted on the member or support, which is thus immobilized in relation to the bushing.