Abstract: A perimeter light blockout system for minimizing light leakage between light gaps such as, for example, between the sides of a covering (e.g., shade) of an architectural-structure covering and the interior side surfaces of a window frame, or between the covering and the outer surface of an interior wall is disclosed. The perimeter light blockout system including a light blocking device and a mounting element for coupling the light blocking device to the interior side surface of the window frame, or the outer surface of the interior wall. The light blocking device may include rear and front channel members. The mounting element may be a mounting extrusion. Alternatively, the mounting element may be a spring clip. In use, the light blocking device may be adapted and configured so as not to contact the covering as the covering moves between extended and retracted positions. The mounting element may include a degree of adjustment so that the light blocking device may be aligned with an out-of-skew window frame.

Abstract: A cordless blind device that can be operated in various types such as manual, semiautomatic, and automatic types is proposed. The cordless blind device includes: a winding roll, a screen, a driving motor, a weight connected to a lower end of the screen; a torsion spring applying torque in a direction in which the screen is wound; and a rotation conversion module transmitting power in two directions between the driving motor and the winding roll, in which when the driving motor does not generate driving force, the torque applied by the torsion spring, the torque applied by the weight, and resistance by the rotation conversion module and the driving motor make equilibrium, so the screen remains stopped, and when an external force is applied upward or downward to the weight, the equilibrium of the forces breaks, so the screen is wound on or unwound from the winding roll.

Abstract: The quick release device may comprise a shade tube, a gear wheel engaging with the shade tube, a pawl removably engaging with the gear wheel and a solenoid configured to activate the pawl. The activation of the pawl disengages the pawl from the pawl wheel and allows the shade tube to rotate. The quick release device may also include a shade tube, a rotating brake plate engaging with the shade tube, a spring configured to apply pressure to the rotating brake plate and a magnet configured to apply magnetism to the spring. In response to the magnet applying magnetism to the spring, the spring contracts and releases pressure on the rotating brake plate and allows the shade tube to rotate.

Abstract: An improved roller shade system provides increased support, additional adjustments and/or increased safety. The slip plate allows the brake to slip forward and minimize damage to the clutch spring when a user pulls too hard on the hembar. The center drive mechanism extends through a bracket to allow the drive shaft to distribute power in both directions and drive two shade tube simultaneously. The tube adapter absorbs force from the spinning shade tube to minimize damage to the other components and the bead chain. The sprocket has a back wall supporting the sprocket, allowing the sprocket 130 to rest on the back flange of the sun gear to minimize pressure on the gears. An adjustment arm is adjusted to help level the shade band. The shade bands may be removed without disturbing the other shade bands in the system. A height of a hembar may be adjusted by rotating a rod within the hembar.

Abstract: A racked fence gate assembly comprises an upright having a longitudinal opening and a lateral opening. The assembly also includes an insert received within the longitudinal opening and coupled to the upright. The insert also includes a support portion extending from a rear wall. The assembly further includes a rail having trimmable areas at proximal and distal ends that is at least partially received within a cavity of the insert at a racking angle, the rail including a channel configured to at least partly receive the support portion therein.

Abstract: A gate may generally include a gatepost and a plurality of rails pivotally connected to the gatepost and having a plurality of posts hingedly attached to at least one of the plurality of rails. The gate may include a lift system having a translating device in communication with a sprocket, wherein the lift system provides an adjustable force to rotate the plurality of rails from a horizontal position to an upward position. The adjustable force may be provided by a turnbuckle. The gate may include a ground anchor system that allows axial rotation of the plurality of rails about a longitudinal axis of the gatepost.

Abstract: A system includes a clamp that includes a first arm, a second arm, and a threaded rod coupled to the first arm and the second arm. The threaded rod is configured to be substantially vertical when the clamp is clamped to the static structure. The clamp is configured to, while the user on a ground surface and in response to the nut being rotated about the threaded rod, a first jaw is urged towards a second jaw such that the static structure is clamped between the first jaw and the second jaw. The system further includes a first bracket configured to be releasably affixed to an upper portion of a first side rail of a base station of an extension ladder, and a second bracket that is configured to be releasably affixed to a lower portion of the first side rail of the base station of the extension ladder.

Abstract: A fall arrest system includes a ladder configured to provide access to an elevated structure and a fall arrest device configured to be secured to the elevated structure, the fall arrest device including an upper anchor, the upper anchor including a first end configured to be secured to the elevated structure and a second end distal from the first end.

Abstract: A hydraulic tool includes a rotor rotatably disposed within a stator. At least an inner portion of the stator and/or at least an outer portion of the rotor is configured to be installed in a drill string in either of two inverted orientations along a longitudinal axis of the hydraulic tool. The rotor is configured to rotate within the stator in either of the two orientations. A method includes disposing a rotor within a cavity defined by a stator, passing a fluid through the stator to rotate the rotor, and reversing the stator or the rotor. A drilling system includes a fluid source, a hydraulic tool, a drive shaft operatively associated with the rotor of the hydraulic tool, and a drill bit operatively associated with the drive shaft.

Abstract: An apparatus for drilling curved and straight sections of a wellbore is disclosed that in one non-limiting embodiment includes a drilling assembly configured to include a drill bit at an end thereof that can be rotated by a drive in the drilling assembly and by the rotation of the drilling assembly, and wherein the drilling assembly includes: a deflection device that (i) tilts a section of the drilling assembly within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore by rotating the drill bit by the drive; and (ii) straightens the section of the drilling assembly when the drilling assembly is rotated to allow drilling of a straight section of the wellbore.

Abstract: A cutting head includes a main body that is attachable to an ice drill shaft at a top side. The main body includes a bottom side that has a bottom peripheral surface. The cutting head includes at least one cutting edge that is disposed on the main body. The cutting edge is configured to perform a cutting operation at the bottom side of the main body. The cutting head includes a cutting rate control pad that is disposed on the bottom side of the main body. The cutting rate control pad extends away from the bottom peripheral surface.

Abstract: A drill bit device may include a cutter housing delimited by an outermost surface and various walls forming a socket. The drill bit device may include various main cutters disposed on an outermost surface of the cutter housing. The various main cutters may be configured to move in an outward direction upon receiving a predetermined pressure. The drill bit device may include various pre-charged cutters disposed immediately behind the various main cutters inside the cutter housing. The various pre-charged cutters may be configured to move in the outward direction upon receiving the predetermined pressure. The drill bit device may include a gate that connects the cutter housing to an internal groove that may be directly connected to a port switch that may allow release of the predetermined pressure through the internal groove and into the gate.

Abstract: A vortex-induced vibration (VIV) suppression apparatus comprising: a strake having a cylindrical body portion dimensioned to encircle an underlying tubular, a fin portion extending radially outward from the body portion and helically positioned around the body portion, and a gap formed through the body portion and the fin; and a connecting assembly configured to facilitate attachment of the strake to an underlying tubular.

Abstract: This disclosure provides an expansion joint apparatus that has a releasable coupler that holds the tool in a locked position for run-in purposes. Once in position, the releasable coupler can be activated to release a tubular housing from an outer mandrel located within the tubular housing to allow for independent movement between the tubular members comprising the expansion joint apparatus.

Abstract: A centralizer assembly replaces an existing centralizer of a wireline tool so the tool can be used with smaller casing, such as casing smaller than 6-in. The assembly includes first and second centralizer units that replace the existing centralizer on a mandrel. Each unit has a sleeve that fits in a recess of the mandrel, and each unit has slider blocks disposed together in the recess on opposing sides of a divider on the sleeve. Arms hingedly connected to the blocks on each unit connect together at a joint having a roller for engaging in the casing. On each unit, a common pin is disposed through the slider blocks, and biasing elements on the common pin bias the blocks toward one another with different amounts of bias.

Abstract: A helical solid profile attached and originating from the outer diameter of a composite or steel sucker rod and extending approximately to the inner diameter of the production tubing, running axially along the sucker rod body and affixed to it for reinforcement and stabilization of the sucker rod tension member body in axial alignment to the central axis of the production tubing which the sucker rod member is housed in, whereas the helical solid profile is made of material which is for acceptable use within the production system environment, the helical solid profile purpose being to control and reduce the sucker rod's deflection during compressive moments, extending the life of the sucker rod or reduction in stress and erratic buckling cycles.

Abstract: Completion systems and methods to perform completion operations include a completion system that includes a tubular having a wall that defines a flowbore. The completion system also includes a first port disposed in the wall and configured to provide fluid communication between the flowbore and the annular region, and a communication path disposed at least partially within the wall and configured to provide fluid communication with an annulus of a well outside of the zone. The completion system further includes a second port disposed in the wall and configured to provide fluid communication between the flowbore and the communication path, a first diverter seat disposed in the flowbore uphole of the second port and configured to receive a diverter flowing through the flowbore; and a second diverter seat disposed in the flowbore uphole of the diverter seat and configurable to receive a second diverter flowing through the flowbore.

Abstract: A helical strake for suppressing a vortex induced vibration (VIV) of a tubular. The helical strake having a shell dimensioned to at least partially encircle an underlying tubular, the shell having at least one fin opening; and at least one fin dimensioned to be positioned within the at least one fin opening formed by the shell, the at least one fin having a base portion dimensioned to be positioned along an underlying tubular and a tail portion dimensioned to extend through the at least one fin opening and radially outward from an underlying tubular.

Abstract: A method of unthreading an up-hole drill rod from a down-hole drill rod includes breaking a joint using a first vise and a second vise, the second vise being in a first axial position, rotating the up-hole drill rod to fully unthread the up-hole drill rod from the down-hole drill rod, moving the second vise to a second axial position and moving the unthreaded up-hole drill rod away from the down-hole drill rod and into alignment with a rod loading region of the rod storage structure, after the up-hole drill rod is aligned with the rod loading region of the rod storage structure, extending the rod handling device to receive the up-hole drill rod in rod receivers, moving the second vise axially to the first axial position, and retracting the rod handling device to move the up-hole drill rod to the rod storage structure.

Abstract: A drilling rig includes an interchangeable plurality of drill pipes, wherein drill bits are arranged at an end section of an end drill pipe. The drill bit being attached to the end section by means of a threaded connection and torque being provided to the drill bit by means of a splines coupling. The drilling rig comprises a lower support device and a breaker device. The system includes a drill bit storage device arranged to hold a plurality of drill bits, a gripping arm for selective gripping of a drill bit. The gripping arm may further comprise a movement sensor, arranged to monitor movement of the gripping arm, and the system may further comprise a control unit. The control unit being arranged to receive input from the sensors and the drilling rig, and to control movement of the gripping arm, the gripping means, the drill bit storage device, and the breaker device of the drilling rig.

Abstract: Systems, methods, and apparatuses for deploying a lost circulation fabric (LCF) to seal a lost circulation zone during a drilling operation. The LCF may be contained within a lost circulation fabric deployment system (LCFDS) that is coupled to a tubular of a drilling string. The LCFDS may include a controller and sensors to detect the presence of a lost circulation zone and deploy the LCF upon detection of the lost circulation zone. In some implementations, a plurality of LCFDSs may be disposed on the tubular and work in cooperation to deploy a plurality of LCFs to form a seal along the lost circulation zone.

Abstract: Provided is a system for emplacing an electrically activated lost circulation material within a wellbore. The system may comprise a bottom hole assembly connected to a drill string, with an activation tool that may be provided along the bottom hole assembly. The system may comprise an activation tool with a non-conductive isolation sleeve having an inner bore, electrodes exposed to an outer surface of the isolation sleeve, conductive cables electrically connecting the electrodes to one of an anode terminal and a cathode terminal, and a seat extending into the inner bore. Further provided is a method for plugging a loss zone in a wellbore that may use at least one activation tool. The method may include circulating an electrically activated lost circulation material to the loss zone and delivering electricity from a power source to electrodes of the activation tool to solidify the electrically activated lost circulation material.

Abstract: A removable screen panel assembly for a vibratory screening machine for separating liquids and solids. The screen panel assembly includes a plate, a corrugated screen assembly supported by the plate, hook assemblies connected to opposite ends of the plate, and gaskets connected to the hook assemblies. A first hook assembly has a first end connected to a first end of the plate, a middle portion spaced above first apertures at the first end of the plate, and a second end parallel to the plate. The second end of the first hook assembly and the first end of the plate sandwich a first end of the corrugated screen assembly.

Abstract: A bit saver assembly having an inner valve sleeve that actuates upon the weight-on-bit (WOB) of the drill bit exceeding a threshold value to overcome the countervailing force provided by a spring contained within the bit saver assembly and the internal flow pressure of the drilling fluid at the area of the inner valve sleeve. Actuation of the inner valve sleeve opens a fluid passage to the wellbore annulus resulting in a reduction of drilling fluid flow pressure and the stretch of the drill string thereby reducing WOB of the drill bit without operator assistance.

Abstract: Embodiments herein relate to apparatus for selecting between direct manipulations of a downhole tool and shifting of the operational mode of a downhole tool, and more particularly to a mode selector tool coupled with a J-Slot mechanism for the downhole tool, the selector enabling either an unimpeded shifting of, or a locking, of the J-Slot mechanism and connected downhole tool.

Abstract: A downhole tool includes a sleeve having a first end and a second end, a slip assembly coupled to the second end of the sleeve, a first cone positioned at least partially in the sleeve, proximal to the first end thereof, and a second cone positioned at least partially in the slip assembly. The first and second cones are configured to be moved toward one another from a run-in configuration to a set configuration. When actuating from the run-in configuration to the set configuration, the sleeve is forced radially outward by the first cone. When actuating from the run-in configuration to the set configuration, the slip assembly is forced radially outward by the second cone.

Abstract: A downhole tubular cutting system includes a cutter comprising an explosive material configured to cut a tubular. The system further includes a generator body coupled to the cutter on an end of the cutter such that the generator body will be oriented uphole or downhole of the cutter when the cutter is positioned with the tubular. A detonating cord or igniter fuse is disposed around the generator body.

Abstract: This disclosure provides an agitator system that includes an agitator assembly of concentric power-sections, (one power-section inside another power-section both of which comprise stators and rotors). The agitator system includes a controller configured to control a valve assembly of the agitator assembly to selectively open and close the valve assembly to allow fluid to selectively flow between the power-sections of the agitator assembly that generates pressure fluctuations or pressure pluses in the fluid pressure, which increases the speed of the rotor or rotors, and thus, the vibrational frequency of the agitator. The controller can be used to increase the vibrational frequency of the agitator assembly when necessary to prevent the drill string from becoming lodged in a wellbore.

Abstract: A tubing hanger assembly including an outer hanger body (8) lands on a load shoulder (10) of a tubing head. Additionally, an inner hanger body (9) having at least one inner hanger groove (19) moves vertically up and down with respect to the outer hanger body and engages at least one downhole device. A first latch ring (11) expands into a groove (12) of the tubing head to lock the outer hanger body in position and a sleeve (14) with a plurality of grooves (20) is disposed between the outer hanger body and the inner hanger body of the tubing hanger assembly. Furthermore, a second latch ring (15), disposed between the sleeve and the inner hanger body, expands into or collapse out of the at least one inner hanger groove (19) and the plurality of grooves (20) on the sleeve (14), and the second latch ring (15) is a tension loading support for the inner hanger body.

Abstract: A polished rod sealing device for an oil pumping machine includes a built-in stuffing box. The built-in stuffing box is arranged inside oil pipe enlargement press cap and can seal the polished rod of the oil pumping machine. The sealing device maintains dynamic coaxiality between the polished rod and the stuffing box, and reduces eccentric wear of the sealing packing resulted from the polished rod. The sealing device also provides lubrication between the polished rod and the sealing packing.

Abstract: An arrangement is for providing a flowable solidifier into a subsea hydrocarbon well comprising a valve assembly with an opening to a well bore. The arrangement has a connection device comprising a well control unit with a lubricator device with a first through opening, an inlet connector with an inlet for the flowable solidifier to a second through opening. The arrangement further has an elongated injection tubing with a third through opening. The injection tubing is adapted to be displaced through the lubricator device to a certain position enabling the third through opening to receive the flowable solidifier from the inlet of the inlet connector and extending into the opening of the valve assembly so that one or more valves of the valve assembly are shielded from interaction with the flowable solidifier.

Abstract: A subsea chemical injection system and method for injecting chemicals into a hydrocarbon production assembly adjacent the seabed wherein a seawater volume flowmeter is utilized to measure seawater pumped through the system and a chemical subsea mass flowmeter is used to measure a chemical injected into the seawater, where the chemical subsea mass flowmeter measures the chemical at a pressure less than the seawater pumped through the system. Based on the chemical subsea mass flowmeter measurement, the flowrate of a chemical injected into the seawater can be adjusted to a predetermined setpoint corresponding to the flowrate of seawater pumped through the system. The chemical subsea mass flowmeter includes a Coriolis tube and chemical injection process pump housed within a pressure vessel. The subsea chemical injection system may be carried on a skid.

Abstract: The present invention relates to a downhole method for providing a zonal isolation at a predetermined position in an annulus between a wall of a borehole and a well tubular metal structure having a longitudinal extension in an existing well, comprising inserting a downhole tool in the well tubular metal structure, positioning the downhole tool opposite the predetermined position, separating a first section of the well tubular metal structure from a second section of the well tubular metal structure by machining into and along a circumference of the well tubular metal structure, inserting an unexpanded annular barrier between the first section and the second section, and expanding the annular barrier for providing zonal isolation at the predetermined position.

Abstract: The present disclosure relates to an integrated collet and a downhole plugging system, and a plugging method thereof. The integrated collet includes a collet body, wherein the collet body can form a seal with an inner wall of a downhole casing and is anchored to the inner wall of the downhole casing; an internal channel is formed inside the collet body along an axial direction; and an inner wall of the internal channel of the collet body is a conical surface.

Abstract: Systems and methods for managing a loss circulation zone in a subterranean well include a tool housing located on a surface of a tubular member with a tool cavity that is an interior open space within the tool housing. An electromechanical system is located within the tool cavity and has a printed circuit board, a microprocessor, a sensor system, a power source, and a communication port assembly. A release system can move a deployment door of a deployment opening of the tool housing between a closed position and an open position. The deployment opening can provide a flow path between the tool cavity and an outside of the tool housing. The release system is actuable autonomously by the electromechanical system. A releasable product is located within the tool cavity and can travel through the deployment opening when the deployment door is in the open position.

Abstract: Methods for forming a seal in a wellbore. An example method includes positioning an expandable metal sealing element in the wellbore; wherein the expandable metal sealing element comprises a composite material of expandable metal and a reinforcement material. The expandable metal forms a matrix and the reinforcement material is distributed within the matrix. The method further includes contacting the expandable metal sealing element with a fluid that reacts with the expandable metal to produce a reaction product having a volume greater than the expandable metal.

Abstract: Apparatus, systems, and methods for reverse circulation cementing a tubular string in a wellbore. One such method includes reverse circulating cement slurry down an annulus defined between the tubular string and the wellbore. During the reverse circulation, a flow control device located in the tubular string is closed to prevent, or at least reduce, flow of the cement slurry from the annulus into the tubular string. The closure of the flow control device causes a pressure pulse in the wellbore. After the flow control device is closed, the reverse circulation is stopped. During a time interval between the closure of the flow control device and the stoppage of the reverse circulation, a shock absorber associated with the flow control device absorbs the pressure pulse in the wellbore so that a pressure in the wellbore is maintained within an acceptable range.

Abstract: Systems and methods for removing and replacing a first sealant in a subterranean well include a running sub located at an end of a running string. A helical guide port extends through the running sub. A port exit of the guide port is at a downhole end of the guide port and extends through a sidewall of the running sub. An inner assembly is extendable through the guide port. A head assembly is located at a drilling end of the inner assembly. The head assembly is sized to pass through the port exit and is oriented to drill a helical path within the first sealant radially exterior of the inner casing and form a void.

Abstract: A cementing system and method for selectively providing bottom-up cementing and top-down cementing of a liner during a single downhole trip are provided. The cementing system has three configurations. A first configuration of the tool allows fluid flow through a central flowbore of the cementing tool, a liner hanger setting tool below the cementing tool, and the liner. A second configuration of the tool routes fluid from the central flowbore of the cementing tool to an annulus surrounding the liner hanger setting tool and the liner. A third configuration of the tool reestablishes flow through the central flowbore of the cementing tool and enables a dropped ball to reach the liner hanger setting tool.

Abstract: A modular hydraulic intensification system includes a housing configured to be deployed within a subsea landing string. The modular hydraulic intensification system also includes multiple hydraulic intensifiers positioned within the housing, wherein each hydraulic intensifier includes a first chamber configured to fluidly couple to a hydraulic fluid supply and a second chamber configured to fluidly couple to one or more landing string valves within a lower portion of the subsea landing string. The modular hydraulic intensification system further includes a shuttle valve fluidly coupled to the respective second chambers of the multiple hydraulic intensifiers, wherein the shuttle valve is configured to enable flow of an output fluid across the shuttle valve from the respective second chambers of the multiple hydraulic intensifiers and to block backflow of the output fluid across the shuttle valve toward the respective second chambers of the multiple of hydraulic intensifiers.

Abstract: Flow control systems are described for variably resisting flow of a fluid composition dependent on the surface energy of the fluid composition. Surface energy is a measure of the wettability of a surface with a particular the fluid. Surface energy dependent flow resistors of the present disclosure include a support structure extending across and/or filling a control passageway such that the surface area exposed to a fluid may be maximized. The flow control systems described may autonomously distinguish between fluid compositions having high and low proportions of a desired fluid component even when the fluid compositions have substantially equal viscosities. Flow control valves are described which may be employed in downhole production and injection equipment.

Abstract: A polymetaphosphate composition and method for temporarily sealing a perforation in a wellbore to facilitate a treatment therein and a well tool which can include a flow path, and a flow blocking device which selectively prevents flow through the flow path. The well tool can include a polymetaphosphate composition. A method of constructing a downhole well tool can include forming a structure of a solid mass comprising a polymetaphosphate composition, and incorporating the structure into the well tool.

Abstract: A downhole fluid control apparatus comprises first and second conduits for providing communication between a pressure source and a downhole device, and a valve provided within a housing and configurable between a first configuration in which the first and second conduits are in pressure communication via the valve, and a second configuration in which the first and second conduits are isolated from each other. The apparatus further comprises an actuator for operating the valve. The actuator is in pressure communication with the first and second conduits and with an ambient region external of the apparatus such that when the pressure within each of the first and second conduits is lower than the ambient pressure the valve is configured in its first configuration, and when the pressure within at least one of the first and second conduits exceeds the ambient pressure the valve is configured in its second configuration.

Abstract: A shifting tool can include a flow restrictor outwardly extendable in a well. A method can include flowing a fluid through a flow restriction, thereby creating a pressure differential and, in response, shifting a closure member while the fluid flows through the flow restriction. Another method can include positioning a shifting tool in a tubular string, then outwardly extending keys from the shifting tool in response to fluid pressure applied to the shifting tool, then engaging the keys with a profile formed in a closure member, and then shifting the closure member between open and closed positions.

Abstract: A downhole tool actuator includes a housing defining an axial bore and a first port extending radially from the axial bore, as well as a piston disposed and movable within the axial bore of the housing. The piston includes a receptacle wall, a shaft extending axially from the receptacle wall, and a contact member extending across the shaft. The receptacle wall defines a chamber and a second port extending radially from the chamber. The contact member is positioned outside of the housing and is configured to engage a downhole tool.

Abstract: A dual valve downhole tool for reverse cementing in a wellbore can include: a body configured to fit within a casing string; an inner sleeve located within the body; a first valve located within the body and configured to open and close a fluid flow path through the body, and wherein the first valve is configured to be in an open position during placement of the downhole tool in the wellbore; and a second valve located within the body and configured to open and close the fluid flow path through the body, wherein the second valve is configured to be in a closed position during placement of the downhole tool in the wellbore, and wherein shifting of the inner sleeve after placement of the downhole tool closes the first valve and opens the second valve. Reverse cementing can commence after the second sleeve has converted to the open position.

Abstract: Some examples of the present disclosure relate to a method for washing an annulus that at least partially surrounds a casing in a well. The method comprises locating a tool inside a wellbore casing, and flowing a washing fluid from an injection aperture on the tool and into the annulus via a first casing aperture in the casing. An inflow region of the casing is created having a reduced pressure relative to the annulus, and the method involves flowing the washing fluid from the annulus and into the inflow region of the casing through a second casing aperture in the casing.

Abstract: Treatment chemicals (for example, scale inhibition chemicals) can be applied to fluids in a pipeline by diverting a side stream of the produced water from a pipeline into a vessel containing a solid material to release of an active fluid treatment agent from the solid material into the diverted produced water; merging the diverted produced fluid containing the active fluid treatment agent into the pipeline; and adjusting a flow rate of the diverted side stream of the produced water to change a level of the active fluid treatment agent in the flow of produced water in the pipeline. Treatment systems can include a pipeline, a vessel containing a solid treatment material; a bypass line providing a fluid connection between the pipeline and an inlet of the vessel; and a return line providing a fluid connection between an outlet of the vessel and the pipeline.

Abstract: The present invention describes methods, systems, and apparatuses for controlled delivery of wellbore fluids including analysis and treatment within the methods, systems, and apparatuses themselves.

Abstract: A method may include obtaining well activity data regarding various wells in a reservoir region of interest. The method may further include determining a predetermined well assignment for various parallel processing stages using a bin-packing problem algorithm and the well activity data. The predetermined well assignment may assign the wells to the parallel processing stages. A respective parallel processing stage among the parallel processing stages may perform a portion of a reservoir simulation using a respective computer processor and a well among the wells. The method may further include simulating the reservoir region of interest based on the wells being simulated according the predetermined well assignment for the parallel processing stages.