Abstract: A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation.

Abstract: The present disclosure relates to passive flow control devices or FCDs and modeling methods applicable to same. In particular, a new method to extrapolate the value of a reference FRR tool to other tools with the same architecture, but different ratings. Instead of scaling the output of the model, the data of the available characterizations is used to extrapolate what the characterization results would be to the different FRR. This estimated data set is then used to fit a new model for the uncharacterized FRR tool.

Abstract: The subject matter of this specification can be embodied in, among other things, a wearable computer device positionable on a human body. The wearable computer device is configured to receive sensor information from a collection of sensors that includes a first sensor and a second sensor, the first sensor attached to the human wearable device and the second sensor connected to the human wearable device, the sensor information describing operational attributes of the oil and gas drilling or production operations that either implements a hydrocarbon recovery process or a hydrocarbon recovery machine at a time of obtaining the sensor information, identify baseline sensor information describing operational attributes during normal operation of either the hydrocarbon recovery process or the hydrocarbon recovery machine, compare the sensor information and the baseline sensor information, and provide a notification indicating an operational condition of the oil and gas drilling or production operation.

Abstract: Process for stimulating and maintaining the activity of a microbial consortia within a subterranean solid carbonaceous medium to produce methane are described. The process comprises the steps of: (A) dosing a first nutrient composition into the microbial consortia environment, (B) monitoring the microbial consortia environment, including the generation of methane therein; (C) dosing a second nutrient composition into the microbial consortia based upon the results of step (B); and (D) repeating steps (B) and (C) and, if required, (E) dosing a further nutrient composition into the microbial consortia environment based upon the results of step (D).

Abstract: A wellbore select fire switch retaining member system and method with an integrated through wire and ground wire in a switch sub. The system/method includes a retaining member that has a form factor acceptable by a conventional switch sub. The retaining member incorporates an electrical connection to the center pin of a pressure switch. The system further includes a secondary piston aligned with a piston in the switch (switch piston) so that external pressure is fully acted upon the entire switch piston creating a reliable switch connection. Another system includes an integrated retaining member and switch module having a form factor compatible with existing switch subs. The integrated module inputs include a ground wire and a through wire and the outputs include a ground wire, through wire and an arming wire.

Abstract: A plunger for oil and gas wells includes a shaft and a sleeve carried by the shaft. The sleeve defines a passageway located between a surface of the sleeve and a portion of the shaft, and the sleeve is longitudinally translatable relative to the shaft from a first configuration to a second configuration and vice versa. In the first configuration the plunger inhibits fluid flow through the passageway, and in the second configuration the plunger permits fluid flow through the passageway. The plunger further includes a force dissipating element interposed between the shaft and the sleeve. The force dissipating element at least partially dissipates forces caused by at least one of (1) the sleeve stopping relative to the shaft after translating from the first configuration to the second configuration; and (2) the sleeve stopping relative to the shaft after translating from the second configuration to the first configuration.

Abstract: A system for producing hydrocarbons from a subterranean well includes an electrical submersible pump assembly with a pump, intake, protector, and motor. A production tubing is in fluid communication with the electrical submersible pump assembly and has an inner bore sized to deliver well fluids containing both gases and liquids from the electrical submersible pump assembly to a wellhead assembly. A packer assembly circumscribes the production tubing downstream of the electrical submersible pump assembly. An inverted shroud has a closed end located between the intake and the protector and an opposite open end that is open towards the packer assembly.

Abstract: A water injection flow control device includes a stack of discs or cone-like plates that form spiral-shaped flow conduits. The spiral-shaped flow conduits form at least one revolution about a central point or axis and depart or approach the central point or axis for each revolution. At least some of the spiral-shaped flow conduits have sections in series with alternating cross sectional area for flow and at least some have sections with a serpentine-type shape for flow along the spiral-shaped flow conduits. The spiral-shaped flow conduits have an inlet coupled to an inner or outer end of the spiral shaped flow conduits, an outlet coupled to the other end of the spiral-shaped conduits, and a control member.

Abstract: A method for increasing efficiency in emulsion production for a steam-assisted gravity drainage (SAGD) oil well system includes generating a causal model of the SAGD oil well system and training the causal model of the SAGD oil well system utilizing historical time series data relating to one or more SAGD oil wells at one or more SAGD production sites of the SAGD oil well system. The historical time series data is obtained from a plurality of sensors in the SAGD oil well system. The method also includes utilizing the causal model to determine a forecast emulsion production and a forecast set of control parameters associated with one or more of the SAGD production sites of the SAGD oil well system. The method further includes adjusting a set of controls of the SAGD oil well system based on the forecast emulsion production and the forecast set of control parameters and subject to one or more constraints associated with the SAGD oil well system.

Abstract: Methods include combining an amount of water and an acid retarding agent (RA), where the amount of water is present in an amount up to about 5 times the mass of the RA, inclusive, and wherein the RA includes at least one salt compound. An amount of acid is dissolved in the combined amount of water and RA to form a composition, where the amount of acid is a molar ratio of acid:RA of between 4.0 and 0.2, inclusive, and wherein the amount of acid is up to about 36% by weight of total weight of the composition. The composition is injected into a wellbore penetrating a subterranean formation at a pressure, which may be less than the fracture initiation pressure of the subterranean formation in some cases, while in other cases equal to or greater than the fracture initiation pressure.

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 gas extraction method in which high energy gas fracturing technology is used to form a fracture network in a thermal injection borehole. Then high-pressure, cyclically temperature-changing steam is injected into the borehole using a spinning oscillating-pulse jet nozzle to form oscillating superheated steam, alternatingly impacting and heating the coal body. The high energy gas forms a fracture network that provides channels for passage of the superheated steam, while oscillating changes in steam temperature and pressure also promote crack propagation and perforation of the coal body; the combined effect of alternation of the two enhances gas desorption and extraction efficiency.

Abstract: There is provided apparatuses, and related systems, for effecting production of oil from a reservoir. A separator is provided and configured to mitigate problems with solid debris accumulation within the wellbore. A system is also provided, including the separator, and is disposed within a wellbore. A pump is also provided, and disposed in fluid communication with, and downstream from, the separator, for receiving reservoir fluids from which gaseous and solid material have been separated by the separator.

Abstract: Apparatus, systems, and methods for controlling activities on a drilling rig are described. The methods include installing a control system operably coupled to the drilling rig and having a user interface, receiving operational guidelines from the user interface that include a plurality of control limits associated with operational parameters of the rig, monitoring current values of the operational parameters, and automatically applying the control limits to the operational parameters during operation of the rig.

Abstract: A tool for use in a borehole penetrating a formation method and a method for using the tool is disclosed. The tool includes a gyroscope for obtaining a first measurement of a rotation rate of the apparatus and at least one accelerometer for obtaining a second measurement of the rotation rate of the apparatus. A processor generates an estimate of the rotation rate using at least one of the first measurement of rotation rate and the second measurement of rotation rate. The estimate of the rotation rate is sued to determine a rotational position of a formation parameter measurement obtained during rotation of the apparatus in the borehole.

Abstract: Methods and systems are described for monitoring the integrity of a subsea pipeline network to transport the production fluid from a subsurface wellhead to surface facilities. More specifically, the described methods and systems are for monitoring the integrity of a riser pipe network and can include installing one or more inclinometers to the buoyancy tank and/or vertical riser structures.

Abstract: Examples of techniques for monitoring a component used in well operation are disclosed. In one example implementation according to aspects of the present disclosure, a method may include: receiving, by a processing system, sensor data from a sensor, wherein the sensor collects data relating to a component used in the well operation; analyzing, by the processing system, the sensor data to determine whether the component used in the well operation is experiencing an error condition; and alerting, by the processing system, a user of the error condition when it is determined that the component used in the well operation is experiencing an error condition.

Abstract: Systems and methods for using pressure signals to assess effectiveness of a diverter in a stimulation wellbore are disclosed. A pressure signal in an observation wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the observation wellbore. The fluid in the observation wellbore may be in direct fluid communication with a fracture emanating from the observation wellbore. The pressure signal may include a pressure change that is induced by a fracture being formed from a stimulation wellbore in the subsurface formation. The pressure signal may be a pressure-induced poromechanic signal. The slope in the pressure signal before and after the diverter are provided into the stimulation wellbore may be assessed to determine the effectiveness of the diverter.

Abstract: A portable locator and method for establishing the location of the cable line in a region which includes at least one generally straight electrically conductive cable line extending across the region from which cable line a locating signal includes a first arrangement for measuring a local flux intensity of the locating signal at a first above ground point within the region with the portable locator in a particular orientation at the first above ground point. A second arrangement uses the local flux intensity to establish a cable line angular orientation which limits the possible directions to the cable line relative to the particular orientation of the portable locator at the above ground point. A third arrangement uses the measured local flux intensity to establish an actual direction of the cable line that is selected from the possible directions based on certain characteristics of the locating signal.

Abstract: An apparatus and methods for testing and pumping through a well servicing system are provided. The apparatus includes a drive mechanism and an actuation system. The actuation system is coupled to the drive mechanism for selectively engaging the drive mechanism to a drive train of the well servicing system's pumping equipment for pressure testing and low rate pumping of the well servicing system without using the primary mover of the pumping equipment. A method for hydrostatic pressure testing of the well servicing system includes putting a transmission of the drive train into neutral and containing the well servicing system, then engaging the drive mechanism to the drive train and activating the drive mechanism to drive the drive train for pumping and compressing test fluid into the well servicing system without using the primary mover.

Abstract: A pumping system for use in a subterranean wellbore below a surface includes a motor assembly, a pump driven by the motor assembly, and one or more sensors configured to measure an operating parameter within the pumping system and output a signal representative of the measured parameter. The pumping system further includes a wireless telemetry system that is configured to transmit data representative of the measured parameter from the pumping system to the surface. The one or more sensors may include acoustically active sensors that operate according to surface acoustic wave principles.

Abstract: EM-telemetry remote sensing wireless systems include a plurality of downhole tools in a drilling area, an array of electrodes at the earth's surface, a noise reduction manager, and an acquisition system. Each downhole tool transmits a modulated current into the formation to generate an electromagnetic signal at the earth's surface. The array of electrodes comprises a plurality of nodes. Each node has a plurality of electrodes that receives the signal. The signal received by the node has a signal component from the tool and a noise component from the area. The noise reduction manager has a de-mixing vector that filters the noise component of the signal and increases a signal to noise ratio. The acquisition system located on earth's surface wirelessly receives signal from each node.

Abstract: A transmitter for inground use controls a depth signal transmit power in relation to a data signal transmit power such that one reception range of the depth signal at least approximately matches another, different reception range of the data signal. A portable device can form a system with the transmitter in which the portable device scans a plurality of frequencies within at least one low frequency depth signal range to measure the electromagnetic noise at each one of the plurality of frequencies and identify at least one of the frequencies as a potential depth frequency for the transmitter. The portable device can include a dual mode filter having a rebar mode and a normal mode filter. The depth signal frequency is dynamically positionable in relation to low frequency noise.

Abstract: Method and apparatus for controlling wellbore operations include a wellbore communication system comprising: a control sub-assembly with a first control unit, a second control unit, one or more downhole sub-assemblies interchangeably mounted on and carried by a bottom hole assembly, each downhole sub-assembly configured to wirelessly send and receive signals from the second control unit.

Abstract: A system including a transmitter mounted inside a pressure bulkhead of a drill tool transmitting a light at a first wavelength is provided. The system includes a receiver mounted inside the pressure bulkhead to detect a second light at a second wavelength. The system also includes a wavelength multiplex unit positioned within the first pressure bulkhead for coupling the light at the first wavelength and the light at the second wavelength with an optical coupler. The optical coupler provides the light at the first wavelength to an external medium via a pressure resistant window and receives the light at the second wavelength from the external medium via the pressure resistant window. A method of using the above system to transmit and receive messages in a downhole optical link is also provided.

Abstract: Systems, methods, and devices for evaluating proper cement installation in a well are provided. In one example, a method includes receiving acoustic cement evaluation data having a first parameterization. At least a portion of the entire acoustic cement evaluation data may be corrected to account for errors in the first parameterization, thereby obtaining corrected acoustic cement evaluation data. This corrected acoustic cement evaluation data may be processed with an initial solid-liquid-gas model before performing a posteriori refinement of the initial solid-liquid-gas model, thereby obtaining a refined solid-liquid-gas model. A well log track-indicating whether a material behind the casing is a solid, liquid, or gas—may be generated by processing the corrected acoustic cement evaluation data using the refined solid-liquid-gas model.

Abstract: A system can include a well tool operable to transmit a fluid through an interior of the well tool. The system can also include a transmitter coupled to the well tool. The transmitter can select a parameter of a pressure waveform using a Gray code that corresponds to the parameter and generate the pressure waveform in the fluid.

Abstract: Systems, computer-implemented methods, and non-transitory computer-readable medium having a stored computer program provide characterization of multiphase fluid flow (MPF) using approximate entropy calculation techniques to enhance measuring and monitoring of a flow regime in a segment of pipe for hydrocarbon-production operations. The systems and methods can be optimized using principal component analysis.

Abstract: A method can include receiving formation parameter values associated with a bore of a formation via a pressure transient analysis of a test performed by tubing that is operatively coupled to a tool that includes at least one pressure sensor. The method can include receiving a pressure stabilization value for fluid flow at a location in the bore of the formation. And, the method can include, based at least in part on the formation parameter values and the pressure stabilization value, calculating a skin factor value for the location in the bore.

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

Abstract: Systems and methods for estimating surface of fracture per volume of rock are provided. The systems include a logging tool, such as a resistivity tool, for generating a borehole image representative of segments of fractures in one or more planes and a processor for estimating surface of fracture per volume of rock (P32) from the segments without the need for defining the one or more planes bearing the segments. The methods include using a downhole logging tool, such as a resistivity tool, to collect data corresponding to segments of fractures in one or more planes, and estimating surface of fracture per volume of rock (P32) by reconstructing theoretical elliptical fractures from the segment data, calculating length of fracture segment per surface of borehole (P21) for the theoretical elliptical fractures, and deriving P32 from P21.

Abstract: A coring tool including a coring bit operable to obtain a core sample of a subterranean formation from a sidewall of a wellbore extending into the subterranean formation. The coring tool also includes a storage tube, an actuator operable to move the core from the coring bit into the storage tube, and a sensor operable to generate information related to presence of the core within the storage tube.

Abstract: The present invention relates to a method for determination of fluid characteristics in a well, by receiving mass ratios and a molecular ratio; converting the mass ratios into molecular ratios based on predetermined molecular weights; normalizing the converted molecular ratios with the received molecular ratio; minimizing a difference between the normalized molecular ratio and an associated member or an associated sum of members; computing an estimated molecular weight (Mw6+) function of (k+11???M; and if a stabilization criteria is met, the steps are iterated with the estimated molecular weight as one of the predetermined molecular weights.

Abstract: An embodiment of an apparatus for estimating and displaying formation and formation fluid properties includes a sampling device coupled to borehole fluid, the borehole fluid including hydrocarbons released from a region of the formation surrounding an interval of the borehole. The apparatus also includes an analysis unit configured to analyze the sample of the borehole fluid at each of a plurality of sample times and estimate amounts of hydrocarbons in the borehole fluid, and a processing device configured to estimate one or more ratios of an amount of at least one hydrocarbon gas to an amount of at least another hydrocarbon gas at each sample time, analyze the one or more ratios to estimate a type of hydrocarbon fluid associated with the ratio, and automatically generate a fluid log that displays an indication of the type at each of the plurality of sample times.

Abstract: The invention relates to a milling machine, in particular a road milling machine, a stabilizer, a recycler or a surface miner, comprising a drive means which is configured such that the milling machine performs translatory and/or rotatory movements on the ground, and a working means which is configured such that the ground is machined. The invention also relates to a method for operating a milling machine of this type. The milling machine according to the invention has a control unit 15 to input drive parameters and work parameters. The control unit 15 is distinguished by a selection unit 15C to select an operating mode from a plurality of operating modes. The control and processing unit 20 has a memory 20A which stores at least one predetermined drive parameter which is assigned to the operating mode, and/or at least one predetermined work parameter which is assigned to the operating mode, for each operating mode of the plurality of operating modes.

Abstract: A method for realizing a centralized control platform for large fully-mechanized coal mining face equipment is provided. In the method, on the basis of a coal cutter system, a hydraulic support system, a coal mining face transportation system, an emulsion pump station system, a mobile transformer substation system and a video monitoring system of the large fully-mechanized coal mining face equipment, real-time monitoring, centralized coordination control and information communication network are realized by a high-speed embedded computer UNO-3072A, a high-speed data acquisition card PCI-1716, a PowerBuilder front-end development platform, an SQLServer database, a Modbus TCP/IP communication protocol and an industrial Ethernet, thereby realizing centralized control over the large underground fully-mechanized coal mining face equipment. Automated production of fully-mechanized coal mining faces is realized.

Abstract: In one embodiment, the present disclosure provides a robot automated mining method. In one embodiment, a method includes a robot positioning a charging component for entry into a drill hole. In one embodiment, a method includes a robot moving a charging component within a drill hole. In one embodiment, a method includes a robot filling a drill hole with explosive material. In one embodiment, a method includes operating a robot within a mining environment.

Abstract: A fluid spray for an underground roof support includes a first housing portion, a spray outlet, a second housing portion formed integrally with the first housing portion, and a service port. The first housing portion includes an elongated shaft having a first end, a second end, and a first fluid passage extending between the first end and the second end. The spray outlet is positioned adjacent the second end of the shaft. The second housing portion is positioned adjacent the first end of the shaft. The second housing portion includes at least one port and a second fluid passage between the at least one port and the first fluid passage. The service port is aligned with the first fluid passage, and the service port is selectively opened to provide access to the first fluid passage from the first end of the first housing portion.

Abstract: A mine stopping panel and method of making it are disclosed. In one embodiment, the panel includes first and second channel-shaped panel members having a telescoping sliding fit one inside the other. An elongate end cap fitted in the first panel member. One or more connections between the first panel member and the end cap hold the end cap against movement relative to the first panel member when an extending force is applied to the end cap tending to telescopically extend the first panel member relative to the second panel member. At least one device on the end cap is configured for engagement with the first panel member to resist telescopic movement of the first end cap relative to the first panel member when a contracting force is applied to the first end cap. Other improved mechanisms for resisting contracting forces are disclosed.

Abstract: A method of monitoring a longwall shearing mining machine in a longwall mining system, wherein the shearing mining machine includes a shearer having a first cutter drum and a second cutter drum, includes receiving, by a processor, shearer position data over a shear cycle. The horizon profile data includes information regarding at least one of the group comprising of a position and angle of the shearer, a position of the first cutter drum, and a position of the second cutter drum. The method also includes analyzing the shearer position data, by the processor, to determine whether a position failure occurred during the shear cycle based on whether the computed horizon profile data was within normal operational parameters during the shear cycle, and generating an alert upon determining that the position failure occurred during the shear cycle.

Abstract: A hydraulic radial piston device is provided with a mechanism for reducing pressure pulsations and providing a smooth pressure transition throughout different displacement operations. In certain examples, the hydraulic radial piston device is configured to maintain an amount of precompression and an amount of decompression of hydraulic fluid trapped in a cylinder chamber to be consistent, respectively, throughout different displacement operations.

Abstract: A rotary actuator and a method of using same are disclosed. The rotary actuator includes a rotor having a body and defining a plurality of contact surfaces, and a stator having a body and defining a plurality of inflatable bladders circumferentially spaced about the stator body. The stator is positioned relative to the rotor such that upon sequential inflation of the plurality of inflatable bladders, the rotor is caused to rotate.

Abstract: A heat exchanger has a first plurality of passages extending in a first direction and to receive a first fluid and a second plurality of passages extending in a second direction, and to receive a second fluid, and the first plurality of passages being formed across a cross-sectional face of the heat exchanger, and there being distinct combined flow cross-sectional areas of the first plurality of passages in different locations across the cross-sectional face of the heat exchanger. A gas turbine engine and a method of forming a heat exchanger are also disclosed.

Abstract: A turbomachine includes an endwall with a plurality of circumferentially spaced apart, radially extending blades extending from the endwall. A first one of the blades defines a pressure surface of a flow channel, a second one of the blades defines a suction surface of the flow channel, and the endwall defines an inner surface of the flow channel. The endwall includes a radially raised portion that is raised proximate the suction surface, and a radially depressed portion downstream of the raised portion.

Abstract: A gas turbine blade according to an embodiment of the present invention includes a turbine blade provided in a gas turbine; and a plurality of film coolers formed in a section from a leading edge to a trailing edge of the turbine blade, in which the film cooler includes a cooling channel through which cooling air is introduced and formed in an oval shape; and an outlet through which the cooling air passing through the cooling channel is discharged and extending from an extended end of the cooling channel toward an outer side thereof and formed in an oval shape.

Abstract: A component according to an exemplary aspect of the present disclosure includes, among other things, a wall, a first channel extending at least partially through the wall to a first outlet, and a second channel adjacent to the first channel and extending to a second outlet. The first channel is configured to communicate a cooling fluid along a first swirl flow path and the second channel is configured to communicate the cooling fluid along a second swirl flow path that is opposite the first swirl flow path.

Abstract: An airfoil for a gas turbine engine includes pressure and suction side walls joined to one another at leading and trailing edges and extending in a radial direction. A serpentine cooling passage is provided between the pressure and suction side walls. A passageway adjoins a passage wall and is fluidly interconnected to an upstream turn that has radially spaced apart innermost and outermost contours. The innermost contour is provided at the wall. A resupply hole is configured to exit downstream from the innermost contour.

Abstract: An airfoil for use with a gas turbine engine includes a pressure side wall. The airfoil further includes a suction side wall configured to be exposed to less pressure than the pressure side wall during operation of the gas turbine engine. The airfoil also includes a plurality of ribs defining multiple air passages including at least one triangular air passage partially defined by at least one of the pressure side wall or the suction side wall, and at least one internal air passage bordered on at least three sides by at least two of the plurality of ribs.

Abstract: Disclosed is a turbine rotor device for a gas turbine, the turbine rotor device comprising a turbine rotor body, and a pre-stressed fiber-wound layer, wherein the pre-stressed fiber-wound layer is wound on the periphery of the turbine rotor body to exert a predetermined pre-loading force on the turbine rotor body. Additionally, a rotor, and a gas turbine and a turbine engine having the turbine rotor device are also provided.

Abstract: A steam turbine rotor blade achieving both abrasion resistance and reliability, and a method for manufacturing a steam turbine rotor blade capable of obtaining such a steam turbine rotor blade are provided. A steam turbine rotor blade according to the invention is characterized by including a blade base material and an erosion shield formed on a surface of the blade base material, wherein the blade base material is composed of a titanium alloy, and the erosion shield is composed of a weld overlay layer including a parent phase composed of pure titanium in which a metal element is solid-dissolved or a titanium alloy in which a metal element is solid-dissolved, and a hard phase dispersed in the parent phase.