Abstract: A subsea system includes in-riser equipment, and a surrounding structure configured to be coupled to a marine riser and a subterranean well. The in-riser equipment is positioned within the surrounding structure, and the surrounding structure comprises a power connection extending radially therethrough. The system also includes a power supply located outside of the surrounding structure. The power supply is connected to the in-riser equipment via the power connection through the surrounding structure, to communicate with the in-riser equipment.

Abstract: A wellhead assembly has a tubular wellhead body with a wellhead axial bore and a wellhead radial bore. A hanger has a hanger axial bore and a hanger radial port. A tube moving mechanism moves a tube in the wellhead radial bore between a retracted position, an intermediate position and an extended position. The tube has an inner end that is recessed in the wellhead radial bore while in the retracted position, that protrudes a first distance into the wellhead axial bore while in the intermediate position, and which protrudes a second distance into engagement with the hanger radial port while in the extended position. A landing shoulder on the hanger above the radial port lands on an inner portion of the tube while the tube is in the intermediate position.

Abstract: Degradable downhole tools that include a doped aluminum alloy may degrade via a galvanic mechanism. More specifically, such a degradable downhole tool may comprise at least one component of the downhole tool made of a doped aluminum alloy that at least partially degrades by micro-galvanic corrosion in the presence of water having a salinity of greater than about 10 ppm, wherein the doped aluminum alloy comprises aluminum, 0.05% to about 25% dopant by weight of the doped aluminum alloy, less than 0.5% gallium by weight of the doped aluminum alloy, and less than 0.5% mercury by weight of the doped aluminum alloy, and wherein the dopant is selected from the group consisting of iron, copper, nickel, tin, chromium, silver, gold, palladium, carbon, and any combination thereof.

Abstract: A backup ring assembly has a base ring to support the plastically deformed extrusion barrier when the packer sealing element is set. The base ring has a thin walled tapered extending ring out of the base ring and into the direction of the sealing element. The sealing element fills the annular gap volume between an upper taper on the extending ring and the body of the backup ring such that on setting the pressure internally in the seal material helps to apply a force in a direction toward the mandrel and for the full circumference of the mandrel. This force and the flexibility of the extending ring helps push the extending ring toward the mandrel outer surface to close extrusion gaps between the mandrel and the base ring of the backup ring assembly.

Abstract: A wellbore isolation device includes a tubular body having an inner bore formed longitudinally therethrough. A plurality of centralizing arms is radially extendible from the tubular body. At least one slip is radially extendible from the tubular body. A sealing assembly that is radially extendible from the tubular body is also included and disposed between the centralizing arms and the slip. The sealing assembly includes a radially extendible elastomeric sealing surface and an anti-extrusion device having at least two support members coupled to opposite longitudinal ends of the elastomeric sealing surface. An equalizing port is also included which is disposed in the tubular body and permits, when opened, fluidic communication between external the tubular body and the inner bore thereby equalizing the pressure between external the tubular body and the inner bore.

Abstract: Methods disclosed for reducing the loss of a circulating fluid in a wellbore to an adjacent subterranean formation during a wellbore operation include coiled tubing milling, cleanout and gravel-packing operations. The methods include placing, either before, during, or before and during the operation, a first acid precursor material, and optionally fibers, in contact with the subterranean formation adjacent to the wellbore to at least partially form a temporary reservoir barrier and reduce hydraulic conductivity between the wellbore and the subterranean formation. The first acid precursor material has a first average particle size of about 3000 microns or less.

Abstract: Embodiments of the present disclosure include a method of replacing valve operation methods during fracturing operations including installing a first operator on a first valve of a first fracturing tree. The method also includes installing a second operator on a second valve of a second fracturing tree, the second fracturing tree being adjacent the first fracturing tree. The method also includes removing the first operator from the first valve, the first valve maintaining a position on the first fracturing tree after the first operator is removed. The method further includes removing the second operator from the second valve, the second valve maintaining a position on the second fracturing tree after the second operator is removed. The method also includes installing the first operator on the second valve after the first operator is removed from the first valve and after the second operator is removed from the second valve.

Abstract: A tool for forming a valve seat within a well that is capable of catching an obstruction will prevent flow of fluid downstream of the seat. According to one embodiment of the invention, the seat is formed by expanding a sleeve with a ring positioned around its periphery or as a subsequent step in the process. As the sleeve is expanded over the ring, the seat is formed. Once the seat is formed, an obstruction in the form of a ball or dart is dropped down to the seat. In another embodiment, the sleeve acts as a stop for a secondary valve seat which catches the obstruction. In yet another embodiment, only a portion of the sleeve is expanded and an inlet portion of the sleeve includes a valve seat.

Abstract: An apparatus for treatment of a wellbore is described. The apparatus includes a tubing string having a wall that defines an inner bore and a plurality of ports spaced apart along the wall. The apparatus includes a plurality of port-closure sleeves each covering a corresponding port. The apparatus also includes a movable sleeve initially positioned uphole from the port-closure sleeves. There is an interference fit between the movable sleeve and the port-closure sleeve, enabling the movable sleeve to engage a port-closure sleeve, displace the port-closure-sleeve to open the corresponding port, and then pass past the port-closure sleeve to engage and displace the next downhole port-closure sleeve.

Abstract: Various embodiments of a tool assembly for completion of wellbores and processes of using the tool assemblies are provided. In various example embodiments a tethered receptacle in receipt of a plug member is releasably coupled to a collet. The tool assembly comprises one or more shiftable valves. In a process for controlling fluid flow in a wellbore string, the collet is released from the receptacle. Engagement of the collet with a shiftable valve causes the valve to shift from a port closed to a port open position, and to plug the central bore of a wellbore string with the plug member.

Abstract: A shear bolt can include a body having a shear portion. A port in the body may be used for introducing a fluid into the body. A core disposed in the body may include a chamber at least partially surrounded by the shear portion. A fluid pressure in the chamber and exerted against the shear portion may be increasable in response to the fluid being introduced through the port, such as to increase an amount of stress in the shear portion and prime the shear bolt for shearing. Additionally or alternatively, a support structure positioned in the chamber may be frangible to reduce support to the shear portion in response to the fluid being introduced through the port, for example, to contribute to priming the shear bolt for shearing.

Abstract: Air pollution includes emissions from two sources: fixed sources and moving sources. A fixed source could be an electric power generation facility or a lime kiln. A moving source can be a tail pipe such as one on an automobile. The fixed source's emissions are redirected downward into a depleted hydrocarbon reserve through an injection well. The moving source is attached to a Carbonator which takes calcium oxide from the lime kiln and carbon dioxide from the moving source to produce calcium carbonate. This removes two sources of air pollution, first the use of the Carbonator system to remove Carbon Dioxide Emissions into the Atmosphere as described in the Application and secondly the total injection of all smokestack effluents into depleted reservoirs, removing the smokestack and in an electrical generating station HVDC transmission lines are run to the displaced smokestack, and is thus a solution to air pollution.

Abstract: The present disclosure relates to a magnetic coupling of a downhole tool that includes a first annular array of magnetic sections, a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array, and a barrier disposed between the first annular array and the second annular array, the barrier including an erosion-resistant layer. The present disclosure also relates to a method of bootstrapping a magnetic coupling of a downhole tool. The method includes supplying electrical current from a battery to an electromagnetic coil in the magnetic coupling, transferring rotational motion from the magnetic coupling to an alternating current (AC) source and supplying electrical current from the AC source to the electromagnetic coil.

Abstract: A hydraulic fracturing system comprises a plurality of hydraulic fracturing rigs. Each hydraulic fracturing rig includes an engine, a transmission, and a hydraulic fracturing pump. A driveshaft is coupled between the transmission and the hydraulic fracturing pump to transfer torque from the engine to the hydraulic fracturing pump. The hydraulic fracturing system also includes a fuel consumption data for each hydraulic fracturing rig, and a controller. The controller is programmed to receive a total pump flow and pressure request, and identify a pump flow distribution for each hydraulic fracturing rig of the plurality of hydraulic fracturing rigs based on the total pump flow and pressure request and the fuel consumption data.

Abstract: Hydraulic fracturing design is provided. In one possible implementation, a computer-readable tangible medium includes instructions directing a processor to access initial conditions of a wellbore as well as potential completion types. The computer-readable tangible medium also has instructions directing the processor to determine a desirable finalized fracturing design for the wellbore by iteratively varying one or more fracturing properties for each of the potential completion types.

Abstract: The selection of a candidate formation realization(s) from a plurality of formation realizations may be done with a classification and regression tree (CART) analysis taking into account petrophysical and geological properties. For example, a method may include applying a CART analysis to a plurality of formation realizations using a first formation property as a predictor in the CART analysis, wherein the plurality of formation realizations are for a second formation property and are based on at least one measured formation property, thereby yielding an association between the first and second properties for each of the plurality of formation realizations; analyzing a strength of the association for each of the plurality of formation realizations; and selecting a candidate formation realization from the plurality of formation realizations based on the strength of the association. The identified candidate formation realization(s) may then be used to develop the parameters of subsequent wellbore operations.

Abstract: A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centralizer or further sleeve or screen, and/or optionally by or via first and second support ring.

Abstract: A dual liner assembly for a multilateral fracking system, comprises a junction support liner adapted to be installed in a lateral wellbore at a junction with a main wellbore; an inner liner with an upper portion and a lower portion, the inner liner being positioned inside the junction support liner and extending beyond the junction support liner within the main wellbore and within the lateral wellbore when the assembly is installed; and a cut and release connector adapted to join the inner liner and the junction support liner and to enable detaching of the upper portion of the inner liner from the assembly. A method of multilateral fracking is also described.

Abstract: A system and method for successively fracking a wellbore at spaced intervals along tubing having therein frac ports each openably closed by a sliding sleeve. The system has at least one actuation member and at least one cylindrical sand screen sub insertable into the tubing. Each actuation member has a collet sleeve with a radially-outwardly biased protuberance of a first profile configured to matingly engage an interior groove profile on at least one of the sliding sleeves and slide the sliding sleeve downhole to open the corresponding port. Each cylindrical sand screen sub has a dissolvable plug member or burst plate disposed on one end thereof allowing for the sand screen to be forced into the well by pressure acting against the plug or plate, and has a resiliently-outwardly biased protuberance configured for engaging a mating profile on the tubing and retaining the sand screen sub in a desired position.

Abstract: An installation apparatus for installing a liner in a subterranean formation includes a housing having an internally arranged flexible member operatively connected to a bore-forming device at one end and to a control module at another end. An opening is arranged in a housing wall through which the flexible member and device may be passed. A liner is arranged around at least a portion of the flexible member between the opening and a first support member. The first support member is arranged to move inside the housing in a direction towards the opening, and a second support member is configured to movably support at least a portion of the flexible member in the region between the control module and the first support member. A method of installing a liner in an inverted drainhole is disclosed.

Abstract: A system and method for establishing hydraulic communication between relief and target wells, wherein a relief well is drilled to include a portion of the target wellbore that is axially offset from and substantially parallel to a portion of the relief wellbore. A perforating system is carried by a tubing string in a cased portion of the relief well. The perforating system includes a latch assembly, a non-rotational packer and perforating gun having charges radially oriented in a limited direction. Tubing string parameters are obtained during the run-in of the perforating system, and thereafter the tubing string parameters are utilized to engage the latch assembly with a latch coupling carried by the casing in the relief wellbore. Axial and rotational forces are applied to the tubing string to engage the latch assembly. Discharge of the perforating gun yields perforations only between the relief well and target well, establishing fluid communication.

Abstract: A method of creating and finishing perforations in a hydrocarbon well having a well wall that includes causing a high velocity jet of a material to shoot into the well wall, thereby creating a perforation in the well wall. The method further includes introducing a gas blast into the perforation, for a blast time duration, the gas blast creating an increasing pressure at the perforation until a maximum pressure is reached; and allowing the pressure of the gas blast to undergo a period of rapid decline to a level of less than 50% of the maximum pressure.

Abstract: A device for water drainage and gas production by pressure control and gas lift and a method for collecting formation gas using the device for water drainage and gas production by pressure control and gas lift. The device for water drainage and gas production by pressure control and gas lift achieves water drainage and gas production by means of the combination of pressure control technology and gas lift technology, includes an inner tube, an intermediate tube, and an outer tube buried within a gas well and configured to be nested with each other, the inner tube being provided with a gas-lift valve and a pressure-control valve, the pressure-control valve being connected to a gas pressure source and being able to control the operation of the gas pressure source.

Abstract: Systems and methods for automated upscaling of relative permeability using fractional flow in systems comprising disparate rock types after actual convergence of a production rate and an injection rate using a three-dimensional (3D) reservoir simulator.

Abstract: A method to enhance the production of oil from underground oil deposits recovers the anode exhaust stream components and thermal energy from a fuel cell for injection in a well pipeline to heat, displace and flow oil into a production well pipeline at optimal reservoir pressure and operating conditions. The process recovers and injects the GHG emission stream from a fuel cell anode exhaust stream into an oil reservoir to increase oil production.

Abstract: A system for improving a steam oil ratio (SOR) includes a direct steam generator (DSG) boiler fluidly coupled with a downhole portion of a steam system via at least a DSG outlet, wherein the DSG boiler is configured to schedule super-heat delivered to the downhole portion to optimize the SOR associated with the system

Abstract: A method of extracting hydrocarbons from a subterranean formation comprises forming a suspension comprising reactive particles and a carrier fluid. The suspension is introduced into a subterranean formation containing a hydrocarbon material. At least a portion of the reactive particles are exothermically reacted with at least one other material within the subterranean formation to form a treated hydrocarbon material from the hydrocarbon material. The treated hydrocarbon material is extracted from the subterranean formation. An additional method of extracting hydrocarbons from a subterranean formation, and a method of treating a hydrocarbon material within a subterranean formation are also described.

Abstract: Hydrajetting assemblies provide data communication and the ability to jet abrasive fluid at pumping rates exceeding the abrasiveness rating of downhole devices. A hydrajetting tool includes jetting nozzles to jet a fluid into a subterranean formation. A capillary to house a data communication line is positioned along the housing of the tool. The communication line in run through the capillary and couples to a downflow sensing device having a fluid flow prevention device thereon. During perforating, the fluid flow device is closed, thus causing the pressurized abrasive fluid to jet out the nozzles. Since the sensing device is positioned downflow of the hydrajetting tool, the abrasive fluid may be pumped at a rate exceeding the abrasiveness rating of the sensing device. Also, real-time data may be communicated from the sensing device using the communication line.

Abstract: Methods including introducing a solids-free high-viscosity fracturing fluid (HVFF) into a subterranean formation to create or enhance at least one dominate fracture, introducing a low-viscosity pad fluid (LVPadF) into the subterranean formation above the fracture gradient pressure to create or enhance at least one first microfracture, wherein the LVPadF comprises micro-proppant, and placing at least a portion of the micro-proppant into the at least one first microfracture. Alternatingly introducing a first low-viscosity proppant fluid (LVPropF) and a high-viscosity crosslinked spacer fluid (HVCSF) into the subterranean formation, wherein the first LVPropF comprises proppant aggregates and the HVCSF comprises a gelling agent, a crosslinking agent, and a breaker, and placing at least a portion of the proppant aggregates into the dominate fracture, where the HVCSF separates clusters of proppant aggregates in the dominate fracture.

Abstract: A method for optimizing well spacing for a multi-well pad which includes a first group of wells and a second group of wells is provided. The method includes the steps of: creating a fracture in a stage in a first well in the first group of wells; isolating a next stage in said first well in the first group of wells from said stage; creating a fracture in said next stage in the first well in the first group after the step of isolating; measuring a pressure by using a pressure gauge in direct fluid communication with said next stage in the first well in the first group of wells; creating a fracture in one or more stages in a well in the second group of wells in a manner such that the fracture in the well in the second group of wells induces the pressure measured in the first well to change; and recording the pressure change in the next stage of the first well.

Abstract: A passive multiphase separator is configured to separate gas from a two-phase fluid in a wellbore. The passive multiphase separator includes an intake tube that has an intake end, a discharge end and an interior section between the intake end and the discharge end. The interior section includes a rifled interior surface that induces rotation in fluids passing through the interior section. The passive multiphase separator further includes a head assembly connected to the discharge end of the intake tube. The head assembly includes a crossover tube extending into the interior section, one or more gas vents extending from an interior of the crossover tube to an exterior of the head assembly and a liquid discharge. The passive multiphase separator can be deployed in a variety of hydrocarbon recovery systems.

Abstract: A method and autodriller for drilling a wellbore with a drill rig by rotating a drillstring and a drill bit with a drill rig drive system; applying an initial weight of the drillstring on the drill rig WOB; measuring drill rig properties to derive an anticipated drill bit rotation speed; and changing the weight of the drillstring on the drill rig WOB so that a corresponding change to the downhole weight on the drill bit occurs approximately simultaneously with a change in the anticipated drill bit rotation speed.

Abstract: A coiled tubing deployment system includes an offshore rig having a reel positioned thereon and coiled tubing wound on the reel. A tubing guide is operatively coupled to receive the coiled tubing and to direct the coiled tubing into the water, with a weight sensor positioned to measure the weight of the portion of coiled tubing deployed into the water. A first set of bend sensors are positioned at a first location on the tubing guide to measure a real-time strain assumed by the tubing guide at the first location. A data acquisition system is communicably coupled to the weight sensor and the first set of bend sensors, and receives and processes weight measurement signals and bend sensor signals in order to provide an output signal indicative of a real-time bending fatigue of the tubing guide.

Abstract: Example apparatus, methods, and systems are described for performing bottom hole measurements in a downhole environment. In an example system, a bridge plug is deployed at a downhole location of a cased well, An optical fiber cable is deployed exterior to the casing of the well. The bridge plug includes a sensor and an acoustic signal generator, which transmits acoustic signals through the casing to the optical fiber cable.

Abstract: A method for assessment of an oil and gas flow network comprises: (1) gathering historical data and/or live data relating to the status of multiple control points at different branches within the flow network and to one or more flow parameter(s) of interest in one or more flow path(s) of the flow network d; (2) identifying time intervals in the data during which the control points and the flow parameters are in a steady state; and (3) extracting statistical data representative of some or all steady state intervals identified in step (2) to thereby represent the original data from step (1) in a compact form.

Abstract: Mechanical acoustic actuators and methods for using these actuators to generate controlled acoustic signals to measure silent or quiet parameters are provided. One example method includes using fluid flows (whistle) and/or mechanical shocks between solids (bells) to stimulate the actuators, either proportionally from the parameter targeted for measurement or artificially modulated to create emitters. Some aspects provide for usage of the actuators within an oil and gas well or a fluid conduit, including in combination with arrays of acoustic sensors, to perform sonar array processing monitoring of acoustic wave propagation to derive properties of the media traversed.

Abstract: A system for communicating through a hanger can include an alignment manifold having upper and lower terminals positioned on opposite respective sides of the alignment manifold, each of the upper terminals being in communication with a respective one of the lower terminals. A downhole line connector can be configured to connect to downhole lines, the downhole line connector including terminals aligned with the lower terminals of the alignment manifold. A method of communicating through a hanger can include connecting an alignment manifold to the hanger, the hanger being configured to suspend a tubular from a wellhead assembly, and connecting a downhole line connector to the alignment manifold.

Abstract: An apparatus for communicating signals across a wellbore barrier defined by a first flow completion system component positioned at an upper end of the wellbore and a second flow completion system component mounted within the first flow completion system component includes a first wireless node which is mounted on the first flow completion system component on a first side of the wellbore barrier, the first wireless node being configured to be connected to an external device, and a second wireless node which is mounted on the second flow completion system component on a second side of the wellbore barrier, the second wireless node being located generally opposite the first wireless node and being configured to be connected to a downhole device. The first and second wireless nodes are configured to communicate wirelessly through the wellbore barrier using near field magnetic induction (NFMI) communications.

Abstract: A sensor for monitoring a species which is a component of a fluid. The sensor includes an internal reflection window which, in use, is in direct contact with the fluid. The sensor further includes a mid-infrared light source which directs a beam of mid-infrared radiation into said window for attenuated internal reflection at an interface between the window and the fluid. The sensor further includes a first narrow bandpass filter which preferentially transmits mid-infrared radiation over a band of wavelengths corresponding to an absorbance peak of the species. The sensor further includes an infrared detector which detects filtered mid-infrared radiation transmitted through the first filter and a processor for measuring the intensity of the detected mid-infrared radiation trans mined through the first filter, and determines therefrom an amount of the species in the fluid.

Abstract: Electromagnetic field monitoring methods and systems for obtaining data corresponding to subsurface rock formations. An electromagnetic field monitoring system includes an electromagnetic transmitter located downhole in a well bore and configured to radiate electromagnetic radiation into a subsurface formation; a fiber optic cable coupled with a fiber optic interrogator, the at least one fiber optic cable and the interrogator located at the surface; and an array of electromagnetic sensors integrally formed in the fiber optic cable and configured to detect the electromagnetic radiation radiated through the subsurface formation. A method of detecting electromagnetic radiation at the surface of an oil well includes transmitting, from an electromagnetic transmitter, electromagnetic radiation into a subsurface formation; and sensing, from the subsurface formation, electromagnetic radiation at the surface of the oil well.

Abstract: A system for downhole telemetry is provided herein. The system employs a series of communications nodes spaced along a tubular body either above or below ground, such as in a wellbore. The nodes allow for wireless communication between one or more sensors residing at the level of a subsurface formation or along a pipeline, and a receiver at the surface. The communications nodes employ electro-acoustic transducers that provide for node-to-node communication along the tubular body at high data transmission rates. A method of transmitting data in a wellbore is also provided herein. The method uses a plurality of data transmission nodes situated along a tubular body and a specially configured network to accomplish a wireless transmission of data along the wellbore using acoustic energy.

Abstract: Disclosed is a downhole tool comprising a fast hybrid telemetry module, and electronics module, and an acoustic flow meter tool module. Suitably, the fast hybrid telemetry module, the electronics module, and the acoustic flow meter tool module are assembled in series. Initially, the acoustic flow meter tool module is preferably provided for regular measurement of fluid temperature, fluid velocity, and fluid density in downhole oilfield production applications. Preferably, the electronics module is provided for data processing and self-compensation of the acoustic flow meter tool module (i.e., automated adjustment of acoustic wave energy and signal conditioning settings to perform flow rate measurements in a wide range of well bore conditions). Finally, the fast hybrid telemetry module is configured for bidirectional data transmission between the downhole tool and a surface data acquisition and monitoring station.

Abstract: Provided are systems and methods for developing a hydrocarbon reservoir including determining properties of a well including a wellbore extending into a tested layer of a multi-layer hydrocarbon reservoir including a barrier located between the tested layer and an adjacent layer of the multi-layer hydrocarbon reservoir, determining a point in time at which a value of a rate of influx of production fluid across the barrier from the adjacent layer and into the tested layer corresponds to a production contribution tolerance value for the well, determining a derivative of a profile of pressure in the targeted layer as a function of radial distance from the wellbore of the well at the point in time, and determining a drainage radius for the well corresponding to the derivative of the profile of pressure in the targeted layer and a pressure derivative tolerance value.

Abstract: An earth-boring drilling tool comprises a cutting element. The cutting element comprises a substrate, a diamond table, and at least one sensing element formed from a doped diamond material disposed at least partially within the diamond table. A method for determining an at-bit measurement for an earth-boring drill bit comprises receiving an electrical signal generated within a doped diamond material disposed within a diamond table of a cutting element of the earth-boring drill bit, and correlating the electrical signal with at least one parameter during a drilling operation.

Abstract: A method for characterizing a hydraulic fracture in a subsurface formation includes inducing a pressure change in a well drilled through the subsurface formation. At least one of pressure and pressure time derivative are measured in or at a location proximate to a wellhead for a selected length of time. At least one of a physical parameter, a time derivative, and a change in the parameter with respect to time of the physical parameter of at least one fracture is determined using the measured at least one of pressure and the time derivative of pressure.

Abstract: This disclosure relates to a downhole acquisition tool having a formation testing module. The formation testing module includes a fluid chamber comprising a piston and configured to store a fluid and to receive a flowback fluid from a geological formation, wherein the fluid is substantially free of solids. Additionally, the formation testing tool has a first conduit fluidly coupled to the fluid chamber and extending from a flowback conduit and a first outlet of the formation testing module, wherein the flowback conduit is configured fluidly coupled to the geological formation and configured to receive the flowback fluid from the geological formation, and wherein the first conduit is configured to receive the flowback fluid from the flowback conduit. Further, the formation testing module has a first flow control device positioned downstream from the fluid chamber, wherein the first flow control device is configured to control a flow of the fluid exiting the fluid chamber.

Abstract: A method is provided, including: forming an optical computing device having a first plurality of sensing elements selected to measure a characteristic of a sample, generating a transmission function from a first add-on integrated computational element (ICE), and evaluating, with a merit-function and the transmission function of the add-on ICE, a predictive performance of a modified optical computing device that includes the add-on ICE in addition to the first plurality of sensing elements. Also, modifying the first add-on ICE to improve the predictive performance of the modified optical computing device according to the merit-function and a modified transmission function of the add-on ICE.

Abstract: A method includes pumping fluid from outside of a downhole tool through a flowline of the downhole tool with a pump. The method further includes taking a first plurality of measurements over time using at least one sensor and estimating a future saturation pressure of the fluid within the flowline at constant time increments via a processor based at least in part on the first plurality of measurements and a saturation pressure model. The method further includes adjusting the flowline pressure to maintain the pressure of the flowline above the estimated future saturation pressure.

Abstract: A new kind of solid-liquid-solid cyclic phase change heat engine is presented with optional but highly recommended multiple cylinders aka multiple stages cascading powertrain. Unlike the traditional Rankine engine or Stirling engine, hereby the gaseous phase is prohibited, and the conventional turbine is abandoned too. Under the drive of heat flux, low expansion volume of the working Phase Change Material (PCM) replaces the high expansion volume of hot gas, and in compensation, high expansion pressure replaces the low expansion pressure of hot gas. Via the isolated transformation from PCM pressure to hydraulic oil pressure, plus fluidic AC-DC rectification, a standard hydraulic motor replaces the gas or steam turbine. Multi-cylinder cascading heat engine can linearly increase up efficiency close to the ideal Carnot efficiency.

Abstract: The scroll compressor (2) comprises a hermetic enclosure (3) comprising a midshell (4), an upper cap (5) and a baseplate (6), the baseplate (6) comprising a mounting base (32) having a plate shape and including a central opening (33), and a central cap (28) arranged within the central opening (33), the central cap (28) comprising a concave portion (29) and a first cylindrical rim portion (30) extending upwardly and having an outer diameter substantially corresponding to an inner diameter of the midshell (4); a compression unit (11) configured to compress refrigerant; and an electric motor (21) configured to drive the compression unit (11) via a drive shaft (19). The mounting base (32) comprises a second cylindrical rim portion (34) extending upwardly and surrounding the central opening (33), wherein an inner diameter of the second cylindrical rim portion (34) substantially corresponds to the inner diameter of the midshell (4) and to an outer diameter of the first cylindrical rim portion (30).