Abstract: A pressure pulse generator and an RSS may change the pressure of a fluid flow through a BHA. If the dogleg at the BHA is less than a target dogleg, then the pressure pulse generator goes into pass-through mode to increase the pressure at the RSS and thereby increase a pad force of the RSS steering pads, increasing the severity of the dogleg. If a downhole tool is stuck, then the pressure pulse generator and the RSS are simultaneously actuated to unstick the downhole tool. The RSS is used to generate and transmit pressure pulses to a downhole tool.

Abstract: A linear escapement mechanism is provided for actuating a downhole tool in a controlled and predictable manner, such as in response to a certain number of pressure cycles. In an example, the actuator includes an escapement sleeve axially moveable with respect to an actuator housing. The escapement sleeve has a plurality of axially-arranged escapement teeth. A rocker secured within the actuator housing has opposing first and second pallets. An operating sleeve is reciprocable to rock the rocker back and forth to alternately move the opposing first and second pallets into engagement with the escapement sleeve as the escapement sleeve advances axially in an actuating direction.

Abstract: Systems and methods of the present disclosure relate to actuator assemblies for downhole tools. An actuator assembly comprises a motor, a spring and a hammer. The spring is adjacent to the hammer, and the hammer operable to compress the spring. The spring is operable to expand. The assembly also includes an anvil adjacent to the hammer. The anvil is operable to move a portion of the downhole tool.

Abstract: A crown plug for a tree of an oil/gas well/wellhead has a securement arrangement for securing the crown plug within the tree. The main body of the crown plug comprises a solid body creating the barrier within the production bore. The solid body creates a robust, strong and reliable barrier. The crown plug is retained within the outer member through inward distortion which secures the crown plug. The securement arrangement arises from an inward radial force that distorts the outer member inwardly to grip a component located within the outer member. The outer member elastically deforms and the outer member returns to a released position once the clamping force is released. Two concentric oppositely arranged tapered surfaces move axially to create the inwardly directed force. The clamping force and the solid body together provide an improved crown plug which is easy and reliable to operate.

Abstract: Linear wellhead connection systems and related methods of pumping fluid into a plurality of wellheads. The linear wellhead connection system uses linear movement of an inlet conduit to transition between multiple discharge conduits that are connected to different wellheads to pump pressurized fluid from a manifold to the different wellheads. The inlet conduit is moveable in a linear direction along a track system relative to the discharge conduits.

Abstract: A system for conveying a fluid produced from at least one producing subsea well to an existing host facility via a flowline includes a support structure having at least a deck, a mooring system, and a plurality of topsides modules. The mooring system anchors the support structure to a seabed and passively positions the support structure proximate to the at least one producing subsea well. The support structure elevates the deck above a water's surface and is normally unmanned. The plurality of topsides modules are disposed on the deck. The topsides modules include at least: a power generation module; a switchgear module a flowline heating module; a chemical injection module; a water injection module; a subsea control module; and a control module that communicates with a remote command center.

Abstract: Subsea acoustic insulation is used to mitigate noise associated with any one or a combination of a deep-water production tree, a deep-water manifold or structure, subsea pumping equipment, or subsea compression equipment. A subsea oil and gas facility includes subsea equipment having one or more devices that generate noise during operation, and subsea acoustic insulation surrounds at least a portion of the subsea equipment and is configured to attenuate the generated noise.

Abstract: A system includes a Christmas tree (XT) having at least one valve, the XT being coupled to a wellbore. The system also includes a pressure boundary tool adapted to provide a secondary boundary for the XT. The pressure boundary tool includes a plug body to be positioned against a valve member of the at least one valve; a seal to be energized into a valve body of the at least one valve; and a plate arranged proximate the seal, the plate being moveable between a first position and a second position, the first position energizing the seal and a second position deenergizing the seal. The pressure boundary tool is positioned within the XT on a side of the valve member closer to the wellbore.

Abstract: A method may include monitoring an operation or a state of one or more subsystems of a hydraulic fracturing system. The hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment, and one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs. The hydraulic fracturing system may further include one or more missile valves, one or more zipper piping and zipper valve sets, one or more well head valves, and one or more well heads. The method may further include controlling, based on monitoring the operation or the state, the one or more subsystems within operating limits or based on operating expectations to cause or prevent an occurrence of one or more well integrity-related events.

Abstract: A fluid diverter system for use in well drilling operations, the fluid diverter system includes one or more plug chambers mounted within a pipe, and a first valve positioned adjacent to one of the one or more plug chambers, the first valve rotationally mounted within the pipe to selectively rotate between an open position and a closed position, the open position allows fluid flow through a main bore as created by the one or more plug chambers while blocking fluid flow around a perimeter of the one or more plug chambers; and the closed position allows fluid flow around the perimeter of the one or more plug chambers while blocking fluid flow through the main bore; the first valve is machined and manufactured as a single unit.

Abstract: A combination of an autofill tube and an interchangeable ball cage for use in an autofill conversion assembly during well operations includes the tube extending to a downhole opening, the tube has a mounting mechanism to releasably mount the tube within an outer member; the interchangeable ball cage having a main body forming a bore; a downhole opening; circulation ports; and an attachment mechanism removably connecting the main body to the autofill tube; the downhole opening has a diameter selected to prevent a conversion ball from falling therethrough; the circulation ports provide fluid flow through the interchangeable ball cage such that the circulation ports have a number and size to create a preset maximum flowrate associated with the combination of the autofill tube and the interchangeable ball cage; and the interchangeable ball cage is to be selected based on the preset maximum flowrate desired at a well site.

Abstract: A frac sleeve system includes a well casing with a tubular wall having a frac port defined therethrough for hydraulic fracturing. A sleeve within the well casing includes a sleeve body. The sleeve is mounted for axial movement relative to the tubular wall of the well casing among three positions including: a closed position in which the sleeve body blocks the frac port, a frac position in which the sleeve body clears the frac port so the frac port is open for hydraulic fracturing therethrough, and a production position in which the sleeve at least partially blocks the frac port.

Abstract: Methods for storing carbon dioxide in a subsurface formation include identifying a plurality of negative geologic closures in the subsurface formation. The dimensions of the plurality of negative geologic closures are characterized. Layers of subsurface formation in the vicinity the negative geologic closures are characterized. One of the negative geologic closures is selected for bottom-up storage of carbon dioxide based on the characterized dimensions and layers.

Abstract: A retrievable connection module for establishing a fluid flow between a subsea station and a subsea flow line. The connection module includes a first fluid port, a first connection profile, a second fluid port, a second connection profile, and a utility arrangement which alters or monitors an aspect or a characteristic of the fluid flow between the first and the second fluid ports. The first connection profile is releasably couplable to a flow line to permit a fluid communication between the flow line and the first fluid port. The second connection profile is releasably couplable to the subsea station to permit a fluid communication between a subsea well and the second fluid port. The first connection profile disconnects the flow line and restricts the fluid communication at the first fluid port. The second connection profile disconnects from the subsea station and restricts the fluid flow at the second fluid port.

Abstract: A method of removing wellbore water from a production wellbore includes determining a production flow rate. The method also includes determining a target production flow rate of the production fluid and comparing the production flow rate to a flow rate threshold associated with the target production flow rate. The method also includes determining, based on a result of comparing the production flow rate to the flow rate threshold, that the production flow rate satisfies the threshold. The method also includes activating a fluid moving device fluidly coupled to a wellbore string extending from a terranean surface to the water to inject, into the water, at least one of i) a surfactant, ii) a gas, or iii) a foaming agent, allowing the water and the production fluid to emulsify together and thereby allowing a mixture of water and production fluid to flow to the terranean surface of the wellbore.

Abstract: A system and method for operating a fleet of pumps for a turbine driven fracturing pump system used in hydraulic fracturing is disclosed. In an embodiment, a method of operating a fleet of pumps associated with a hydraulic fracturing system includes receiving a demand Hydraulic Horse Power (HHP) signal. The demand HHP signal may include the Horse Power (HP) required for the hydraulic fracturing system to operate and may include consideration for frictional and other losses. The method further includes operating all available pump units at a percentage of rating below Maximum Continuous Power (MCP) level, based at least in part on the demand HHP signal. Furthermore, the method may include receiving a signal for loss of power from one or more pump units. The method further includes operating one or more units at MCP level and operating one or more units at Maximum Intermittent Power (MIP) level to meet the demand HHP signal.

Abstract: A missile for a hydraulic fracturing system can include a high-pressure (HP) manifold, a low-pressure (LP) manifold, and a main manifold in between. The missile is configured to simultaneously fracture three or more wells. The HP manifold has multiple input channels, an output channel, and a main channel disposed in between. The LP manifold includes a LP input channel, multiple LP output channels, and a LP manifold in between.

Abstract: An operating facility (1) for operating a mine by in-situ leaching comprises a supply manifold (9) for supplying leach liquor to the injector well heads (3), a production manifold (15) configured to discharge leachate to a leachate treatment plant (17), a treatment manifold (19), a facility (20) for providing a treatment solution configured to inject the treatment solution into the treatment manifold (19) and/or into the supply manifold (9); and for each producing well, a production pipe (21) equipped with a production cut-off device (25) and a treatment pipe (23) equipped with a treatment cut-off device (27), fluidically connecting the corresponding producing well head (5) in parallel, respectively, to the production manifold (15) and to the treatment manifold (19).

Abstract: An integrated well construction system (IWCS) operable for constructing a well via integrated control of integrated control devices that collectively control integrated subsystems of the IWCS. The IWCS includes an IWCS communication network, the integrated control devices (each directly connected with the IWCS communication network), the integrated subsystems, and a control workstation (450, 452, 454) directly connected with the IWCS communication network and operable to control each of the integrated control devices to thereby control the integrated subsystems.

Abstract: System and method for measuring the characteristics of drill cuttings. The system comprises at least one camera operably connected to a processor for determining characteristics of particles from cuttings from drilling, wherein said processor is configured to perform particle detection, determine information about said particles, or both. The processor can be configured to initiate, interrupt or inhibit an activity based on the particle characteristics. The method comprises acquiring visual data from at least one camera, performing particle detection using said data, determining information about the detected particles, alerting an operator and/or initiating, interrupting, or inhibiting activity responsive to such information.

Abstract: The drilling machine comprises a control unit and at least one sensor. The drilling machine further comprises a percussive element and a tool, wherein an end of the tool comprises a drill bit configured to strike rock. The percussive element is configured to impact the tool and the tool is configured to transfer impulse energy generated by the percussive element to the drill bit. The method during drilling comprises collecting data depending on force fed into the rock and indentation depth into the rock at an impact of the percussive element. The method further comprises determining a percussion procedure based on the collected data, and determining a deviation between the percussion procedure and a reference percussion procedure. The method further comprises adjusting one or more drilling parameters related to the drilling process based on the deviation.

Abstract: The disclosed embodiments include methods to monitor expansion of a metallic sealant deployed in a wellbore, methods to monitor downhole fluid displacement, and downhole metallic sealant measurement systems. The method to monitor expansion of a downhole metallic sealant includes deploying a metallic sealant deployed along a section of a wellbore. The method also includes exposing the metallic sealant to a reacting fluid to initiate a galvanic reaction. The method further includes measuring a change in temperature caused by the galvanic reaction. The method further includes determining an amount of expansion of the metallic sealant based on the change in the temperature.

Abstract: Dimensions of a tool moving in/out of a well may be measured during well operations. The measured dimensions of the tool may be used to analyze the well operations. Analysis of well operations may include identification of types of well operations being performed at the well, monitoring of the well operations, benchmarking of the well operations, identification of tools being used in the well operations, and/or other analysis of the well operations.

Abstract: A system for tracking and steering a downhole tool using an augmented reality device. A tracker tracks the location of a downhole tool as it moves underground and transmits data to the device, while one or more sensors measure a position and orientation of the device. The device analyzes the data received from the tracker and the sensors and generates a virtual image of the downhole tool. The virtual image is displayed on the device at its detected location relative to the ground surface and relative to the position of the device. The position of the displayed virtual image is modified in response to updated information from the tracker or the sensors. Virtual images representing various parameters of the drilling operation are also displayed on the device in juxtaposition with the virtual image of the downhole tool.

Abstract: An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators.

Abstract: A method includes imaging, at an imaging resolution, a core of a subsurface formation to create a core image and iteratively performing the following operations until a defined feature of a rock of the subsurface formation exceeds a viewable image feature threshold: extracting a number of subsamples from the core for a first iteration and from each of the number of subsamples previously extracted for a subsequent iteration; increasing the imaging resolution; and imaging each subsample. The method includes performing the following operations for the subsamples last extracted: determining at least one formation property characteristic; determining a guiding rock property for each voxel of the core image and the number of subsample images; and determining a subsample that is a shortest distance to the voxel based on the number of guiding rock properties; and mapping, for each voxel, the at least one formation property characteristic that is the shortest distance.

Abstract: The disclosure provides a formation fluid pumping method and pump, and a wellbore system that in one example includes wellbore surface equipment connected to a downhole tool including a formation fluid container having a fluid input port and a fluid output port, and a moveable piston inside the formation fluid container having two fluid chambers positioned to alternately pump a quantity of formation fluid in the formation fluid container from the fluid input port to the fluid output port. The wellbore system further includes a mechanical piston actuator having a rotary portion attached to the formation fluid container and a linear portion attached to the moveable piston, and a brushless direct current motor coupled to the rotary portion of the mechanical piston actuator and controlled to alternately rotate the rotary portion of the mechanical piston actuator in opposite directions to pump the quantity of formation fluid.

Abstract: Embodiments herein relate to a technique that may include identifying historical data related to at least one remote well. The technique may further include identifying, based on the historical data, a correlation between gas flow capacity and estimated ultimate recovery (EUR) of the at least one other well. The technique may further include identifying gas flow capacity of a well. The technique may further include predicting, based on the gas flow capacity of the well and the identified correlation between gas flow capacity and EUR of the at least one other well, EUR of the well. The technique may further include operating the well based on the predicted EUR. Other embodiments may be described or claimed.

Abstract: Testing a fluid in a wellbore with a well testing tool carried on a well testing string includes activating a first selectively controllable longitudinal valve and a second selectively controllable longitudinal valve with a communication module. A first and second packer of the well testing tool engages an inner wall of the wellbore to define a zone of interest between the first packer and the second packer. The communication module further activates a selectively controllable radial valve positioned between the first packer and the second packer to flow fluid between the central bore and the annulus formed between the first packer and the second packer, a fluid sample flows from the annulus between the first packer and the second packer through the testing string to a tophole facility.

Abstract: Computer vision drilling systems and methods may be used with a drilling rig. The computer vision systems and methods may automatically monitor the drilling site and drilling operations, and may tally pipe in the drill string and monitor equipment for anomalous drilling conditions, and may automatically take corrective action as may be needed. The computer vision system may detect and identify one or more markings, such as symbols, letters, numbers, or other identifying features, on the pipe. Such features may be encoded on the pipe, such as by being etched or engraved or otherwise marked on the pipe, and may uniquely identify each pipe. The system can monitor and record the drilling conditions to which each pipe is exposed during drilling, which can be used to determine, among other things, whether and to what extent the pipe can be expected to have a useful life.

Abstract: A drilling apparatus connectable with a drill pipe and connectable with a drilling assembly comprising a drilling assembly housing, for use in drilling a borehole, including a rotation restraining device actuatable between a retracted position and an extended position, a rotation restraining device actuator for actuating the rotation restraining device between the retracted position and the extended position, a swivel actuatable between a locked position and an unlocked position, and a swivel actuator for actuating the swivel between the locked position and the unlocked position. A method for drilling a borehole, including connecting a drilling assembly with a drill pipe, wherein the drilling assembly comprises a drilling assembly housing, drilling while rotating the drill pipe and thereby rotating the drilling assembly housing, and drilling while rotating the drill pipe relative to the drilling assembly housing.

Abstract: A distributed coal cutting device for a Longwall face of a coal mine includes coal cutting units, where each coal cutting unit includes one coal cutting machine and two hydraulic supports, the two hydraulic supports are arranged side by side, the arrangement direction of the two hydraulic supports is parallel to the coal wall of the Longwall face, and the coal cutting machine is connected with one of the hydraulic supports. According to the device, multiple coal cutting machines are used for simultaneously carrying out coal cutting operation, and single-point coal cutting is changed into multiple-point simultaneous coal cutting, so that the coal cutting production capacity and the production efficiency are greatly improved. The multiple coal cutting machines can derive multiple control modes, so that the production flexibility and adaptability are improved.

Abstract: Systems for forming or extending a tunnel or shaft within a working surface may include a ram accelerator assembly for accelerating a projectile into geologic material to weaken a region of the geologic material. A cutting tool may then be used to remove the weakened material. A collection assembly may be used to move debris away from the working surface while the projectile and cutting operations are performed to enable generally continuous use of the system. The number of projectiles that are accelerated and the rate at which projectiles are used may be controlled based on characteristics of the geologic material and the rate at which created debris may be removed.

Abstract: A method for adjusting a surface of an exploratory data model of a geological domain to take into account blast hole data, the method comprising; drilling a plurality of blast holes proximal to the geological domain; recording blast hole data samples for each of the blast holes in an electronic data storage apparatus; operating a processing assembly in data communication with said storage apparatus according to instructions stored in a memory accessible to the processing assembly to perform the following acts: labelling each said data sample as domain or non-domain; determining blast hole boundary samples for the geological domain at each of a number of elevations to produce blast hole boundaries for the geological domain; comparing the blast hole boundaries to a surface of the exploratory data model; adjusting the surface based on the blast hole boundaries for the geological domain to generate an adjusted surface; and mining the geological domain based on the adjusted surface to thereby improve efficiency of

Abstract: A vane for use in a rotary vane pump. The vane has a length L extending between a first edge of the vane and a second edge of the vane and a width W extending perpendicular to said length, the width extending between a third edge of said vane and a fourth edge of the vane, and further comprising a channel extending through said vane and provided at a position along said length L of said vane. The channel maybe positioned away from said first and second edges such that said vane has a constant length L along its width. The width of the channel may vary in shape between first and second points along the length of the vane. The channel may have a triangular shape, a rectangular shape or a circular shape. A method for detecting the decrease in length of the vane is also described.

Abstract: Variable sleeve clearance control systems for gas turbine engines are disclosed. An example variable sleeve clearance control system for a gas turbine engine includes a sleeve comprising a first end and a second end, the first end of the sleeve coupled to a first spring that biases the sleeve inward, and the second end of the sleeve coupled to a second spring that biases the sleeve outward, a proximity sensor to measure a clearance width, and a controller for each of the first and second springs, the controller to obtain the measured clearance width from the proximity sensor and determine a response of the first and second springs.

Abstract: The present invention relates to a heat shield (100) for a supercharging device (1), comprising a first ring portion (110), which is situated at the outside in a radial direction (24) and which is designed to bear the heat shield (100), and a second ring portion (120), which is situated at the inside in a radial direction (24) and which extends from the first ring portion (110). The second ring portion (120) has at least one structure-stiffening feature (200), the at least one structure-stiffening feature (200) being of bead-like form.

Abstract: A drain assembly includes a drain tube and a flapper assembly. The drain tube extends between a first tube end and a second tube end. The first tube end is configured to fluidly attach to an inlet plenum assembly of an engine system of a rotorcraft. The flapper assembly is positioned along the second tube end and comprises a flapper door that is configured to allow fluid to drain from the drain assembly to an engine compartment of the engine system of the rotorcraft. The flapper door is configured to prevent fluid, engine compartment gases, or flame from flowing into the drain assembly through the second tube end of the drain tube.

Abstract: A method repairs welding of an aircraft turbine engine blade that has a lower surface and an upper surface connected by a leading edge and a trailing edge. The blade further includes a free end referred to as the tip. The method includes the repair welding of the tip and including the steps of: securing a first stop to the leading edge at the tip and a second stop to the trailing edge at the tip, depositing a repair weld bead on the tip, from the first stop to the second stop, and removing the first and second stops. The first and second stops are secured solely by squeezing same on the leading and trailing edges.

Abstract: Systems and methods to locate the position of cooling holes on an outer surface of a turbine engine component, based on a three-dimensional measurement along an X-axis, a Y-axis, and a Z-axis, and an extracted two-dimensional measurement along the X-axis and the Y-axis. The two-dimensional data is analyzed to find a common geometric feature of the component and determine a scan area based on the common geometric feature. The component is measured within the scan area to locate a cooling hole located on the outer surface of the component. A surface profile of the cooling hole is extracted along the X-axis and the Y-axis, and an orientation of the cooling hole is extracted along the Z-axis. A three-dimensional coordinate set of the cooling hole is calculated based on the surface profile and the orientation.

Abstract: A rotor disk for a gas turbine engine includes disk posts extending in a radial direction from a disk body. Each of the disk posts includes an insert receiving slot extending axially through the disk post and a disk post pressure surface. Disk post inserts are assembled within the insert receiving slots of each of the disk posts. A blade is retained by disk post pressure surfaces of each of the disk posts.

Abstract: A guide blade arrangement (20) for a turbomachine (1), including a guide blade airfoil (22) and a platform (21). The guide blade airfoil (22) is situated at a side (21.1) of the platform (21) facing the gas channel, an opposite side (21.2) of the platform (21) facing away from the gas channel being contoured at least in one area (30.1, 30.2) with elevations (25) and depressions (26) that follow one another in the circumferential direction (23) in relation to a longitudinal axis (2) of the turbomachine (1), and the elevations (25) and depressions (26) at the side (21.2) facing away from the gas channel being set via a platform thickness (31), taken radially in each case, that is variable in the circumferential direction (23) and that repeatedly increases and decreases with a continuous profile.

Abstract: A lash adjuster can include a hydraulic lash assembly, a mechanical lash assembly, and a check assembly. The hydraulic lash assembly can include a body, a top plunger, a leak down plunger, and the check assembly between the body and the leak down plunger. The mechanical lash assembly can be between the top plunger and the leak down plunger. The mechanical lash assembly can include a shim abutting the top plunger, a spacer, and a spring pressing against the spacer and the shim to form a gap between the top plunger and the leak down plunger. The lash adjuster can include the spring pressing directly against the spacer and directly or indirectly against the shim.

Abstract: A valve rotating device with valve stem seal includes a valve rotating device, with a cylinder head rest and a spring rest intended to bear against a valve spring during operation. The valve rotating device is designed to rotate the spring rest relative to the cylinder head rest during operation. A valve stem seal is attached to the cylinder head rest of the valve rotating device. The valve stem seal being designed to bear against a valve stem and to seal same during rotational and axial movements.

Abstract: A method for checking operability of a first metering unit includes sending a control signal to a second metering unit to dispense a second quantity; comparing the quantity dispensed with the second quantity; sending a control signal to a second metering unit to introduce a third quantity; detecting the pressure drop caused by the introduction of the third quantity; sending a control signal to the first metering unit to introduce a first quantity; detecting the pressure drop caused by executing the control signal to introduce the first quantity; and ascertaining that the first metering unit is not functioning correctly if a difference between the pressure drop detected as a result of the execution of the control signal to introduce the first quantity and the pressure drop detected as a result of the execution of the control signal to introduce the third quantity is above a threshold.

Abstract: An exhaust system with a multipiece heat shield for a work vehicle includes a first shield part and a second shield part. The first shield part surrounds an aftertreatment unit for aftertreating exhaust gases. The first shield part extends in an axial direction. The second shield part surrounds an exhaust tailpipe with radial spacing between the second shield part and the exhaust tailpipe. The second shield extends in the axial direction from the first shield part, wherein a radial gap between the first and second shield parts is sealed by a seal. In a starting position, the seal has two free ends arranged in the circumferential direction of the heat shield, which are arranged adjoining or overlapping one another in the circumferential direction when the seal is in a sealing position.

Abstract: The disclosure is directed to an exhaust gas heating unit for an exhaust gas system of an internal combustion engine. The exhaust gas heating unit includes at least one electrically conductive heating conductor element, wherein the at least one electrically conductive heating conductor element is configured from bent flat strip material. The exhaust gas system conducts exhaust gas defining an exhaust gas primary flow direction (H). The heating conductor element can have a plurality of broad sides arranged to be substantially parallel to the exhaust gas primary flow direction (H) and a plurality of end faces arranged substantially orthogonally to the exhaust gas primary flow direction (H).

Abstract: A heater for an exhaust system that includes a housing having a connector coupled to the exterior thereof, a first terminal and a second terminal that are each disposed to the interior of the housing and electrically coupled to the connector, a heating element coupled to the first and second terminals, a heating wire coupled to the first and second terminals, and a plurality of heating rods inserted into the heating element to conduct heat from the heating wire throughout the heating element, wherein the connector receives power from an external power supply to supply electrical current to the heating element and the heating wire and wherein at least one of the heating rods supports the heating wire. The combination of elements are configured to heat and disrupt the flow of exhaust gases and aid in removing and/or reducing toxic gases and pollutants from the exhaust system.

Abstract: A burner for an exhaust gas tract that can be flowed through by exhaust gas of an internal combustion engine includes a combustion chamber, in which a mixture comprising air and a liquid fuel is to be ignited and thus to be combusted, and an inner swirl chamber that can be flowed through by a first part of the air. The inner swirl chamber has a first swirl generation device via which a turbulent flow of the first part of the air can be caused and a first outflow opening that can be flowed through by the first part of the air flowing through the inner swirl chamber. The first part of the air being able to be removed from the inner swirl chamber via the first outflow opening.

Abstract: An embodiment coolant control module includes a housing including a coolant inlet configured to receive a coolant, a coolant outlet configured to discharge the coolant, an internal passage connecting the coolant inlet and the coolant outlet, and a pump mounting part adjacent to the coolant outlet. The coolant control module further includes a control valve disposed inside the housing and configured to change a direction of the coolant, a coolant pump coupled to the pump mounting part of the housing, a driving motor unit mounted on the housing, connected to the control valve, and configured to drive the control valve, and a controller mounted on the housing, connected to the coolant pump and the driving motor unit, and configured to control an operation of the coolant pump and the driving motor unit.