Abstract: A motor transmission and gearbox are disclosed for downhole use, which include a first motor driving a first input shaft, a second motor driving a second input shaft, and a gearbox comprising at least a ring gear, a sun gear, and a planetary gear and planetary carrier. The first input shaft driving either the ring gear, the sun gear or the planetary gear and/or planetary carrier, the second input shaft driving one of the gears not driven by the first input shaft, and the remaining gear driving the output shaft.

Abstract: Methods of evaluating performance of simulated drilling operations may involve accepting characteristics of an earth formation. A drill path, a plurality of quality evaluation standards, and selection of a bottom hole assembly (BHA) and at least one earth-boring tool may be accepted. A drilling operation attempting to follow the drill path using the BHA and the drill bit may be simulated. Performance of the BHA and the drill bit in the drilling operation may be evaluated relative to the quality evaluation standards. At least one aspect of the simulated drilling operation may be changed, and simulation of the drilling operation, performance evaluation, and change of the aspects of the drilling operation may be iterated. Performance of each drilling operation may be compared to the other drilling operations, and an improved aspect of a drilling operation may be output relative to the comparative performance of the drilling operations.

Abstract: A system and method for performing stimulation operations at a wellsite having a subterranean formation with of a reservoir therein is provided. The method involves generating a plurality of quality indicators from a plurality of logs, and combining the plurality of quality indicators to form a composite quality indicator. The plurality of stress blocks may then be merged using diversion criterion. The composite quality indicator may be combined with the merged stress blocks to form a combined stress and composite quality indicator, the combined stress and composite quality indicator comprising a plurality of blocks with boundaries therebetween. The method may further comprise defining stages along the combined stress and composite quality indicator based on the diverter-assisted stage classifications; and selectively positioning perforations in select stages based on the diverter-assisted stage classifications thereon.

Abstract: A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

Abstract: A pumpdown sub for use with a downhole tool during pumpdown operations includes a valve with a valve member that selectively opens and closes. When the valve is open, fluid can flow axially past the pumpdown sub, thus the downhole tool can be moved up and down in the wellbore without flow resistance from the pumpdown sub. When the valve is closed, the valve member blocks substantially the entire cross sectional area of the wellbore, so that when pumpdown fluid is added to the wellbore, the fluid does not flow around the valve, but instead all of the pumped fluid exerts a pumpdown force onto the valve and tool.

Abstract: An electrical submersible well pump assembly includes a pump driven by an electrical motor. A string of tubing connects to the well pump assembly and extends to an upper end of a well. A power cable installed in the tubing has three insulated electrical conductors embedded within an elastomeric jacket. A metal strip has turns wrapped helically around the jacket. The metal strip is compressed between the jacket and the tubing to cause the power cable to frictionally grip the tubing.

Abstract: Exemplary apparatuses, systems, and methods are provided to produce steam for use in oil field applications. In some embodiments, a catalyst is provided that includes a plurality of ceramic bodies impregnated with an alkaline-promoted manganese oxide. In other embodiments, the catalyst includes a plurality of bodies formed of an active ceramic oxide in a consolidated state without an underlying ceramic body. The bodies are contacted with a liquid hydrogen peroxide having a strength, in one embodiment, between about 30 and about 70 weight percent to produce steam. The steam is directed to an oil field application, such as, but not limited to, a geologic formation to increase oil production from the geologic formation, an applicator to clean oilfield equipment, a heat exchanger to heat hydrogen peroxide, or a heat exchanger to heat living quarters.

Abstract: Embodiments of the present invention relate to heat transfer fluids (e.g. molten-salt) as a thermal buffer for heating, by thermal energy derived from wind-generated electricity, at least one of (i) a subsurface hydrocarbon-containing formation or (ii) a bed of hydrocarbon-containing rocks. During times when wind is plentiful, wind electricity is used to heat the heat transfer fluid—e.g. by means of an electrically resistive heater immersed in the heat transfer fluid. At any time, thermal energy from the wind electricity may be transferred to the hydrocarbon-containing rocks or subsurface formation by the heat transfer fluid. In some embodiments, the fluid is heated both by wind-generated electricity and by solar radiation. Some embodiments relate to a subsurface molten salt heater (e.g. powered by wind-generated electricity) having a non-thermally insulation portion through which molten salt flows.

Abstract: A system and method are provided that use RF energy to enhance the extraction of oil and gas from hydrocarbon bearing strata. A three-dimensional underground electromagnetic array is used to guide RF energy to where that energy is converted to heat in the hydrocarbon bearing strata. The three dimensional underground electromagnetic array is a guided wave structure, as opposed to an antenna structure, to minimize the unwanted effects of the near fields associated with antennas. In one embodiment, the legs of the three-dimensional underground electromagnetic array are composed of production well pipe.

Abstract: Systems and methods for delivery of thermal energy to horizontal wellbores are disclosed. In one embodiment, a method comprises heating a heat transfer fluid; circulating the heat transfer fluid into a vertical bore to a heat exchanger; advancing feedwater into the vertical bore to the heat exchanger, wherein the heat exchanger is configured to transfer heat from the heat transfer fluid to the feedwater to generate steam; transmitting the steam from the heat exchanger into a horizontal wellbore to cause heating of a subterranean region; and returning the heat transfer fluid from the heat exchanger to the surface. The method may further comprise collecting liquefied formation in a second horizontal wellbore; and transmitting the liquefied formation to the surface through a production line.

Abstract: The invention provides methods for performing the appropriate manipulation of pressure-time data during a hydraulic fracturing treatment or test to determine the condition of the created fracture. The mode of growth, dilation, or intersection with one or more natural fractures may be determined accurately and quickly. The methods include the steps of acquiring fracturing data, assessing the fracturing index based on a moving reference point, and establishing the mode of fracture propagation using the fracturing index. The methods provide for the determination of the time of intersection of a hydraulic fractures with one or more natural fractures. The methods also provide for an early warning of sand-out possibility. The data analysis may be performed in real time during the progress of the treatment or test or in a playback mode after the completion of the treatment or test.

Abstract: A wellsite production machine has a separator connectable to a wellhead, the separator having a liquids discharge line and a oil discharge level, an oil storage tank having a liquids input port to which the liquids discharge line is connected; and the storage tank having a high level line established by a high level detection apparatus, the oil discharge level of the separator being at or above the high level line of the storage tank so that liquids in the separator may flow by gravity into the storage tank. The separator and a flare stack assembly are also disclosed, along with a method of making the wellsite production machine.

Abstract: The present invention relates to a subsea system, where the subsea system comprises a separator (1) with an inlet line (2) and an outlet line (3), a compression unit (4) with an inlet line (5) and an outlet line (6) and a heat transfer unit (7), where the outlet line (6) of the compression unit (4) is guided into the heat transfer unit (7), the heat transfer unit (7) being connected to the inlet line (2) of the separator (1). According to the invention the heat transfer unit (7) is used for transferring heat between at least a part of a fluid in the inlet line (2) of the separator (1) and at least a part of a fluid in the outlet line (6) of the compression unit (4).

Abstract: An oil recovery process where produced water is cooled through a flash evaporization process and the resulting vapor is utilized to heat steam generator feedwater.

Abstract: A method for controlling a drilling system comprising a drive system, drillstring and drill bit. The drive system rotates the drillstring during a drilling process to drill a borehole through an earth formation. The method involves setting a desired rotation speed v0 for the drillstring; receiving property measurements of the drilling system and deriving therefrom the component vup of the rotation speed of the drillstring associated with upgoing rotational energy; determining a rotation speed v for the drillstring by optimizing an expression which reconciles two conflicting objectives of: (i) maintaining a stable rotation speed centred on v0, and (ii) minimizing the downgoing rotational energy, the optimized expression expressing v in terms of v0 and vup; and controlling the drive system to rotate the drillstring at v.

Abstract: A drilling system has one or more drilling machines at a drilling site, in communication with a drill planning computer. The drill planning computer includes one or more processors, and a non-transitory computer readable medium in communication with the one or more processors having encoded thereon a set of instructions executable by the one or more processors to receive drill plan parameters, generate a drill plan based on the drill plan parameters, communicate the drill plan to one or more drilling machines, execute the drill plan with the one or more drilling machines, update at least one of the drill plan parameters based on an identified change in drilling conditions, update the drill plan in real-time based on an updated drill plan parameter, and adjust operation of the one or more drilling machines to reflect the changes in the updated drill plan.

Abstract: Methods and apparatuses for determining surface wetting of a metallic material with changing well fluids. In general, the methods according to the invention include measuring electrical impedance spectroscopy (“EIS”) for a system simulating downhole conditions for the wetting of a surface. Methods and apparatuses for making EIS measurements model double-layer capacitance at a downhole surface in a well, from which the nature and quantification of the wetting of the surface can be inferred.

Abstract: Systems and methods for generating a three-dimensional image of a proppant-filled hydraulically-induced fracture in a geologic formation are provided. The image may be generated by capturing electromagnetic fields generated or scattered by the proppant-filled fracture, removing dispersion and/or an attenuation effects from the captured electromagnetic fields, and generating the image based on the dispersion and/or attenuation corrected fields. Removing the dispersion and/or attenuation effects may include back propagating the captured electromagnetic fields in the time domain to a source location. The image may be generated based on locations at which the back propagated fields constructively interfere or may be generated based on a model of the fracture defined using the back propagated fields.

Abstract: Aspects of the disclosure can relate to a system for tracking fatigue damage experienced by a tool in real-time. The system can include a processor operably coupled to a memory and operable to execute one or more modules to generate master curve fitting coefficients for a connection type associated with a tool component (e.g., a component of a bottom hole assembly). The master curve fitting coefficients can be for a threaded connection master curve, a port hole master curve, and so forth. The processor can also be operable to execute the one or more modules to generate a fatigue calculator for the tool component. The system may receive a real-time trajectory for the tool, determine a curvature from the trajectory of the tool, determine a bending moment based upon the curvature, and determine fatigue damage for the tool component based upon the bending moment using the fatigue calculator.

Abstract: A ranging system calculates the distance, direction and orientation of a target well through rotationally invariant analysis of triaxial electric and magnetic field measurements from a bottom hole assembly (“BHA”) having electromagnetic sensors. The triaxial electric and magnetic field sensors can be deployed in any downhole device without explicitly needing to process or retrieve rotational information about the downhole BHA or wireline device. Also, the distance, direction and orientation of the target well can be retrieved from a single measurement position.

Abstract: Methods and systems for allowing the use of very small-diameter sample tubing, with a flexible borehole liner, in multi-level water sampling systems deployed in subsurface boreholes. Methods are disclosed for determining depth distances to a ground water table, in a borehole, without the need to lower a pressure transducer into a sampling tube.

Abstract: Various embodiments disclosed relate to methods and apparatuses for determining a minimum miscibility pressure of a fluid with and oil composition. In various embodiments, the method can include placing a fluid into a pressure chamber at a first pressure. The pressure chamber can include at least one capillary tube having one end disposed in an oil composition in the pressure chamber. The fluid can include at least one of a gas, a liquid, and a supercritical fluid. The method can include measuring a height of the oil composition in at least one of the capillary tubes. The method can include repeating the measuring for at least one cycle using a second pressure different than the first pressure. The method can include determining the minimum miscibility pressure of the oil composition with the fluid by extrapolating the pressure at a height of the oil in the at least one capillary tube of zero from the two or more measurements of the height of the oil composition in the at least one capillary tube.

Abstract: A device for high-temperature applications is provided. The device includes a base member and at least one electrically conducting layer. The electrically conducting layer is made of polycrystalline of a first metal doped with at least one second metal different from the first metal and formed on or above the base member as electrodes for bulk acoustic vibration and/or resonance or as at least one temperature-sensitive element for sensing temperature.

Abstract: A magnetic system for determining an operating position of a downhole tool. The system includes an array of magnets operable to produce a magnetic field that is operably associated with a stationary component of the downhole tool. A moveable component of the downhole tool has at least first and second positions relative to the stationary component. In the first position, the moveable component has a first degree of interference with the magnetic field. In the second position, the moveable component has a second degree of interference with the magnetic field. A magnetic field detector is operable to be run into the wellbore and moved relative to the downhole tool such that the position of the moveable component relative to the stationary component is determined by detection of a magnetic signature produced by the moveable component and the array of magnets.

Abstract: A flowmeter for use in a wellbore that has vane assemblies that deploy from a rotating segment. The vane assemblies project a variable distance away from the rotating segment, so that the flowmeter adjust to varying flow conditions. The variable distance of the vane assemblies also allows use of the flowmeter in different sized wellbores. An example flowmeter includes vane assemblies of varying length that are selectively deployed depending on operating conditions. Other vane assemblies have vane elements with a pitch that varies in response to wellbore and fluid flow operating parameters.

Abstract: Methods for acquiring and interpreting operating parameter data during an operation to inject a work fluid into a wellbore.

Abstract: A method for detecting or mapping potential influx zones for gas from a geological formation to a gas well with a well head with a valve tree or a choke includes the following steps of:—marking the potential influx zones with tracer systems with corresponding unique tracers—filling the gas well form the surface, through the well head with liquid wherein the tracers have affinity to the liquid,—producing liquid form the well,—consecutively sampling samples from the produced liquid,—to analyze the samples to prove possible presence of one or more tracers or even measure the tracers concentrations. [for then proving possible influx of a back flow of liquid from the influx zones one assume implies the gas pressure and the inflow of a gas form the influx zones].

Abstract: Methods of monitoring conditions within a wellbore comprise providing a plurality of signal transmitters and a plurality of signal receivers within the wellbore. Marker materials configured with a particular characteristic may interact with signals generated by the plurality of signal transmitters are introduced into the wellbore. The marker materials interact with the signals, forming modified signals. The modified signals are received by the plurality of signal receivers. The plurality of receivers are configured to measure at least one of acoustic activity and an electromagnetic field to determine a location of the marker materials. The electrical conductivity and the magnetism of produced fluids may also be measured to determine a producing zone of the produced fluid. Downhole systems including the marker materials and also disclosed.

Abstract: In one embodiment of the invention, an air drilling downhole telemetry and control system is disclosed, comprising a telemetry and control interface, a topside unit, one or more repeater units, a bottom hole unit, and an air filled drill string composed of a drill pipe acting as a circular waveguide, wherein the topside unit is disposed at the surface end of the drill string, the repeater units are disposed along the drill string, and the bottom hole unit is disposed at the terminal end of the drill string, and each unit is a communications node along a communications link existing between the telemetry and control interface and the bottom hole unit. Each unit comprises a communications subsystem, a power subsystem, and optionally a telemetry and control subsystem. The communications subsystem contains a message buffer system capable of temporarily storing communications during a communications link disruption event.

Abstract: Methods, techniques, and systems for transmitting a data frame of an electromagnetic (EM) telemetry signal to or from a downhole location can be performed using multi-channel transmissions in which at least two different channels at two different frequencies are used to send a long header and the data frame. At least a portion of the long header is transmitted at a first frequency, and at least a portion of the data frame and any remaining portion of the long header not transmitted at the first frequency are transmitted at one or more additional frequencies different from each other and the first frequency. In one example, only two channels are used: one channel is used to transmit all of the long header, another channel is used to transmit all of the data frame, and either of the channels is used to transmit an identifier identifying the type of the data frame.

Abstract: Certain aspects are directed to capturing data regarding physical states associated with a perforating string. In one aspect, a sensing tool is provided. The sensing tool includes at least one sensor and a processor positioned in an isolated chamber of the sensing tool. The processor samples data from the sensor at a first sampling rate associated with the deployment of a perforating string. The data is associated with at least one parameter with respect to the perforating string. The processor detects a trigger condition associated with a perforation operation of the perforating string. The processor switches to a second sampling rate in response to detecting the trigger condition. The second sampling rate is greater than the first sampling rate and is associated with the perforation operation. The processor samples data at the second sampling rate for a period of time in which the perforation operation is at least partially performed.

Abstract: An acoustic communications network includes acoustic modems that exchange messages on an acoustic communications medium, such as tubing deployed in a wellbore. The acoustic communications medium is characterized by an acoustic transfer function having a plurality of passbands and a plurality of stopbands. The messages are communicated by encoding the message into a plurality of symbols representing the message and distributing the plurality of symbols across a bandwidth of a wideband acoustic signal that spans at least one passband and at least one stopband of the acoustic transfer function.

Abstract: An example apparatus for generating downhole fluid pressure pulses includes a tubular housing defining an internal fluid flow passage and providing a housing wall having an internal surface and an external surface. The apparatus also includes a device for selectively generating a fluid pressure pulse, the device being mounted in an aperture defined in the housing wall and being movable between a retracted position, where the device is seated within the aperture, and a radially extended position, where the device extends at least partially beyond the external surface.

Abstract: Apparatus and methods are provided. An ultrasonic tool with an array of axially spaced receivers and a transmitter is located in a borehole and is activated. Ultrasonic waveform indications recorded by the receivers are processed and analyzed to determine the presence of non-dispersive headwave signatures. If a non-dispersive headwave signature is located, the presence of a solid such as cement in the annulus is confirmed, and one or more of the compressional and shear velocities of the cement can be determined. If only casing dispersive mode signatures are found, the annulus is determined to possibly contain no cement at the location of interest and additional processing is required.

Abstract: Evaluation of formation and fracture characteristics based on multicomponent induction (MCI) log data includes automated calculation of inverted biaxial anisotropy (BA) parameters for the formation by performing an iterative BA inversion operation based on the MCI log data and using a BA formation model that accounts for transfers by axial formation anisotropy to resistivity. The BA inversion operation can be combined with a transversely anisotropic (TI) inversion based on the MCI log data and using a TI formation model, to calculate inverted TI parameters for the formation. The inverted BA parameters and the inverted TI parameters can be used, in combination, to calculate a quantified value for an identification function, to indicate estimated presence or absence of a fracture in the formation.

Abstract: A device and associated method can detect hydrocarbon gas with at least a control module having a plurality of different gas detection means housed in a mobile enclosure, the control module configured to activate at least two different gas detection means to provide amounts and types of gases present in a fluid.

Abstract: Systems and methods for controlling dust. One method includes automatically detecting an operating status of a mining machine. The method also includes automatically, with an electronic processor, adjusting operation of a dust suppression system based on the operating status of the mining machine.

Abstract: A fire and/or water resistant expansion joint system for installation between substrates of a tunnel. The system includes a fire resistant coating applied at a predetermined thickness to achieve a substantially uniform layer on the substrates and a fire and water resistant expansion joint. The expansion joint includes a core having an edge, wherein the substantially uniform layer of the coating extends along the substrates of the tunnel to the edge of the core, and a fire retardant infused into the core. The core is configured to facilitate the compression of the expansion joint system when installed between the substrates. The coating and the fire and water resistant expansion joint are each capable of withstanding exposure to a temperature of at least about 540° C. or greater for about five minutes.

Abstract: An expander for a heat engine, the expander being capable of converting a high pressure gaseous working fluid to useful work, the expander including: •high pressure working fluid supply means; •at least one reciprocating piston reciprocating in a cylinder between top-dead-centre (TDC) and bottom-dead-centre (BDC) with a long dwell time at TDC; •a working fluid inlet valve that opens and closes to introduce, while open, high pressure working fluid from the working fluid supply means into an expansion chamber in the cylinder at or near TDC; •power transfer means that transfers work done on a piston by the working fluid to a form of useful work output; and •an exhaust valve to release expanded working fluid from the expansion chamber to a volume of low pressure working fluid; wherein piston travel is small during transition of the inlet valve from open to closed and from closed to open.

Abstract: A method, including: replacing an original blade shelf (16) of a gas turbine engine blade (10) with a new blade shelf (64) that is located closer to a base (18) of the blade than the original blade shelf; adding mass to the blade until a mass of the blade with the new blade shelf is greater than a mass of the blade with the original blade shelf in order to maintain a same contribution by the blade with the new blade shelf as a contribution by the blade with the original blade shelf to a dynamic balance of a rotor arrangement.

Abstract: The gas turbine engine rotor can have a body having a solid-of-revolution-shaped portion centered around a rotation axis, the body defining an annular cavity centered around the rotation axis, the annular cavity penetrating into the body from an annular opening, the annular cavity extending between two opposite annular wall portions each leading to a corresponding edge of the opening; and at least one structural plate mounted to and extending between the two opposite annular wall portions and forming an interference fit therewith.

Abstract: A morphing trailing edge device for an airfoil includes a skin member, an actuator, and a torsion element. The skin member is configured to extend on a surface of a trailing edge region of an airfoil and includes a load introduction point within a reinforced area. The skin member further includes a stiffening member arranged essentially perpendicular to the load introduction point, wherein the load introduction point, the reinforced area and the stiffening member are integrated into the skin member. The actuator is configured to drive the torsion element with an actuation load. The torsion element is configured to translate the actuation load to the load introduction point, so that the actuation load morphs the trailing edge region up- or downwardly relative to a horizontal plane. A morphing airfoil for an aircraft, an aircraft with a morphing airfoil and a method for manufacturing a morphing airfoil are also described.

Abstract: An airfoil for a gas turbine engine is disclosed. The airfoil may include a leading edge, a sheath on the leading edge; and a grounding element connected to the sheath. The grounding element may have a radially extending tab, and may be configured for connection to a component of the gas turbine engine to form a ground path from the sheath to the component.

Abstract: A composite fan blade for a gas turbine engine, the blade comprises a root portion for connecting the blade to a hub and an aerofoil portion. The aerofoil portion comprises an external cover formed from a non-metallic material and an internal structure enclosed within the cover. The internal structure comprises a plurality of support members extending generally from a pressure side of the internal structure to a suction side of the internal structure, and wherein the plurality of support members define a plurality of cells or channels.

Abstract: There is proposed a method of forming an inflated aerofoil (1), the method comprising the steps of: forming a layered, planar pre-form (30); providing at least one stress-relieving opening (44, 45, 46, 47) through the pre-form; hot creep forming and inflating the pre-form (30) to form an intermediate aerofoil; and subsequently removing material from the intermediate aerofoil, including at least a region containing the or each stress-relieving opening (44, 45, 46, 47), to form a finished aerofoil.

Abstract: The gas turbine component showerhead cooling hole layouts described herein include minimal lateral cooling hole exit diffusion on the middle showerhead cooling hole rows and interior facing sides of outer rows. In this way, rows of cooling holes may be placed close together. Stated another way, the outer showerhead cooling hole rows substantially only include lateral cooling hole exit diffusion in the direction away from the other rows to again allow the rows to be placed close together.

Abstract: A gas turbine engine component has a cooling hole with a metering section. The metering section includes a convex surface and a concave surface, with a first arcuate channel connecting an end of the convex surface and an end of the concave surface. The end of the convex surface and the end of the concave surface define a dimension that is smaller than a diameter of the arcuate channel.

Abstract: A method of manufacturing is presented. The method includes providing a plurality of structural layers comprising a plurality of composite rods, wherein at least one structural layer from the plurality of structural layers is attached to a separation layer. The method further includes stacking the plurality of structural layers, detaching the separation layer from the at least one structural layer, and curing the plurality of structural layers to form a structural component of a wind turbine blade.

Abstract: Methods for selective localized coating deposition for a turbine component include providing the turbine component comprising an exterior surface with one or more surface features and selectively coating at least a portion of the exterior surface using a localized coating deposition apparatus based on a location of at least one of the one or more surface features.

Abstract: A method for forming a coating on a substrate is provided. To an assembly 10 including a substrate 12, a porous matrix 14 on the substrate 12, and an impregnating material 16 on or within the porous matrix 14, the method includes applying an amount of energy 18 from an energy source 20 effective to melt the impregnating material 16 and a portion of the substrate. In this way, the impregnating material 16 impregnates the porous matrix 14. The method further includes cooling the assembly 10 to provide a coating 26 comprising the porous matrix 14 integrated with the substrate 12.