Abstract: A heat-dissipating module includes a thermal conduction structure, at least one heat pipe, and plural fins. The thermal conduction structure includes a connecting part. The connecting part has a first surface and a second surface opposed to the first surface. The first surface is contacted with a digital micromirror device. The heat pipe includes a penetrating part and a suspension arm. The penetrating part runs through the connecting part of the thermal conduction structure from the second surface to the first surface. The penetrating part is contacted with the digital micromirror device. The plural fins are contacted with the suspension arm. After the heat generated by the digital micromirror device is transferred to the suspension arm through the thermal conduction structure and the penetrating part, the heat is transferred from the plural fins to the plural fins and then dissipated to surroundings through the plural fins.

Abstract: An indoor unit of an air conditioner having improved structures of suction, discharge and/or flow passages which may increase operation efficiency, reduce noises and realize a compact size. The indoor unit includes a housing comprising a front panel and a rear panel coupled to a rear portion of the front panel, at least one discharge outlet exposed to a front of the front panel, at least one suction inlet formed in the rear panel at a position corresponding to the discharge outlet, at least one heat exchanger disposed at a front portion of the suction inlet to absorb heat from air introduced through the suction inlet or transfer heat to the air introduced through the suction inlet, and at least one diagonal flow fan disposed between the heat exchanger and the discharge outlet to suction air passing through the heat exchanger and discharge the air through the discharge outlet.

Abstract: Fluid circulation tube and heat exchanger equipped with tubes of this type are disclosed. The tube (6) is produced by bending, and, once its wall has been bent, has a base portion (12) prolonged laterally by two linking portions (13) leading to two top portions (14) turned toward one another, which terminate in end legs (15) turned toward the base portion (12), forming at least two parallel longitudinal internal channels (16) into which the two systems (20) of bends (21) of a corrugated disrupter (17) can be inserted, these systems being interconnected by a central part (23) inserted into a gap left between said legs and the base portion.

Abstract: A heat-dissipation base structure includes a main board and at least one mounting member. The main board has four chamfered corners to form four pressing ends and is provided on an upper face with at least one retaining section. The mounting member is provided with at least one locating section for engaging with the at least one retaining section, and includes at least one outward extended arm portion. The arm portion is formed along a bottom with a downward protruded portion, so an opening is formed on the arm portion at a proximal end of the downward protruded portion for engaging with one pressing end of the main board when the mounting member and the arm portion are mounted to the upper face of the main board. Therefore, the heat-dissipation base structure has increased structural strength and the arm portion is less possibly deformed due to bending stress therein.

Abstract: A heat dissipation device includes a conductive plate and a fastener. The fastener includes a fastening element and an elastic element coiled around the fastening element. The fastening element includes a pole portion and a head portion formed at one end of the pole portion. The conductive plate defines a supporting portion through the conductive plate. The supporting portion defines a hole, an upper groove and a lower groove communicating with one another. The upper groove and the lower groove are coaxial with each other. A flange protrudes from a circumference of the pole portion. The pole portion enters the upper groove. The flange abuts a bottom of the conductive plate and is received in the lower groove. The elastic element elastically abuts the top of the conductive plate.

Abstract: A silicon-based thermal energy transfer apparatus that aids dissipation of thermal energy from a heat-generating device, such as an edge-emitting laser diode, is provided. In one aspect, the apparatus comprises a silicon-based base portion having a first primary surface and a silicon-based support structure. The silicon-based support structure includes a mounting end and a distal end opposite the mounting end with the mounting end received by the base portion such that the support structure extends from the first primary surface of the base portion. The support structure includes a recess defined therein to receive the edge-emitting laser diode. The support structure further includes a slit connecting the distal end and the recess to expose at least a portion of a light-emitting edge of the edge-emitting laser diode when the edge-emitting laser diode is received in the support structure.

Abstract: Methods and devices for dropwise condensation of a refrigerant vapor on a surface are provided. The surface and various aspects of the system are configured to ensure the surface is refrigerant repelling, enhances droplet mobility, increases condensation rate and/or increases heat transfer rate.

Abstract: A thermostat method and apparatus has one or more demand circuits, an energy storage device; a DC regulator connected to the energy storage device, and a thermostat control connected to the DC regulator and to the energy storage device. Current is drawn from the one or more demand circuits when demand associated with the demand circuits is not active and the energy storage device is charged with the current drawn from the one or more demand circuits. If energy stored in the energy storage device is below the first predetermined threshold, activity in the thermostat is reduced and if energy stored in the energy storage device is above the second predetermined threshold, activity in the thermostat is allowed to increase.

Abstract: A cooling system for an internal combustion engine in a vehicle comprises a variable-speed coolant pump and a plurality of heat-transfer nodes coupled in a coolant loop with the pump. Each node generates a flow rate request based on an operating state of the node. A pump controller receives the flow rate requests, maps each respective flow request to a total pump flow rate that would produce the respective pump flow rate request, selects a largest mapped pump flow rate, and commands operation of the pump to produce the selected flow rate.

Abstract: A cooling system for a vehicle includes a flow channel circulating a liquid medium cooling a drive device of the vehicle, a plurality of temperature sensors provided at different positions on the flow channel, a heating element provided on the flow channel and cooled by the liquid medium, and a control device controlling heat generation from the heating element. The control device changes a heat generating state of the heating element, and estimates a flow rate of the liquid medium flowing through the flow channel based on a time lag taken for detecting a temperature change caused by changing the heat generating state by the plurality of temperature sensors. Preferably, the drive device includes a motor, and a power control unit for driving the motor, and the heating element is a power control element in the power control unit.

Abstract: Distributed nodes, such as intelligent register controllers, of a heating, ventilating and/or air conditioning (HVAC) system wirelessly communicate with each other on a peer-to-peer basis, forming a network, and collectively control the HVAC system, without a central controller. The intelligent register controllers collectively control the amount of conditioned air introduced into each region. Each node may base its operation at least in part on information about one or more (ideally all) of the other nodes. Each intelligent register controller automatically determines how much conditioned air to allow into its region, or how much return air to allow to be withdrawn from its region. Each register controller automatically determines when and to what extent to operate its respective controllable damper.

Abstract: A cooling system for an internal combustion engine in a vehicle comprises a variable-speed coolant pump for providing a coolant flow to a plurality of heat-transfer nodes coupled in a coolant loop with the pump. Each node generates a flow rate request based on an operating state of the node. The coolant loop is configurable to a plurality of restriction states. A pump controller receives the flow rate requests, maps each respective flow request to a pump flow rate that would produce the respective pump flow rate request, selects a largest mapped pump flow rate, identifies a restriction state in which the coolant loop is configured, selects a pump speed in response to the selected flow rate and the identified restriction state, and commands operation of the pump to produce the selected pump speed.

Abstract: A heat exchanger has a wind deflector extending along a long side of a finned heat exchange tube array.

Abstract: A Y-tool for use in a wellbore includes: a stem having a bore formed therethrough, a port formed through a wall thereof, and a coupling formed at each end thereof; a branch fastened to the stem and having a passage formed therethrough in fluid communication with the stem port and a coupling formed at an end thereof; and a gasket sealing an interface of the stem port and branch passage.

Abstract: A coiled tubing injector comprises a drive system for independently driving a plurality of chains independently but otherwise retarding relative motion between the driven chains when a chain begins to slip uncontrollably.

Abstract: A pumping assembly includes a hydraulic pump having a hydraulic ram tied to a reciprocating annular piston having a central bore. When the annular piston moves in an upward direction, the hydraulic ram moves toward an extended position extending from the housing. When the annular piston moves in a downward direction, the hydraulic ram moves toward a retracted position retracted within the housing. A polish rod extends up through the central bore of the annular piston and is held in position by a polish rod clamp positioned on top of the hydraulic ram. The polish rod moves with the hydraulic ram. Other pumping systems, devices, and methods are also disclosed.

Abstract: A system is provided for injecting coiled tubing (CT) into and out of a wellbore. In embodiments, separate injector and reel units are provided releasing constraints on CT size and length. The injector unit is fit with an extendible mast for handling larger bottom hole assemblies and fit with a rotating gooseneck for accepting CT from alternate arrangements of the reel unit. The mast is reinforced to resist CT loading. The capacity of the reel is maximized for the reel unit transport envelope. The reel is rotated using an offset drive engaging a bounding reel flange, such as engaging drive and bull gears. A generally radial displacement of the drive from the reel permits replacement of the entire reel.

Abstract: A floating clamping device for an injection head of a continuous oil pipe, including a drive sprocket, a transmission chain, a supporting plate, a pushing plate, clamping oil cylinders and a clamping assembly. At least two clamping oil cylinders are installed on the supporting plate fixedly. The pushing plate is fixed on the supporting plate through a pin shaft. The clamping assembly includes a saddle-shaped clamping block, a clamping block seat and rollers which are mounted on the clamping block seat. The clamping assembly is mounted on the transmission chain. A piston rod of the clamping oil cylinder is pressed on one face of the pushing plate, while the other face of the pushing plate is pressed on the rollers. The pushing plate has a simple structure and is convenient for maintenance; the clamping device has a compact structure and a reduced volume.

Abstract: Certain aspects and features of the present invention are directed to an isolation assembly that can be disposed in a wellbore through a fluid-producing formation. The isolation assembly can include one joint of a tubing section, at least two inflow control devices, and an isolation element. The joint of the tubing section can include at least two ports. Each inflow control device can be coupled to the tubing section at a respective port. The isolation element can be positioned between the inflow control devices. The isolation element can be configured to fluidly isolate the ports from each other.

Abstract: A safety valve can be disposed in a wellbore that is through a fluid-producing formation. The safety valve can include a flow tube that is allowed to move at least partially independent, or free, from a piston assembly to avoid negative effects from forces on the flow tube from a closing assembly, such as one including a flapper. For example, the flow tube may not be required to be rigidly connected to a piston assembly such that the flow tube can move more than the piston assembly moves.

Abstract: Certain aspects and embodiments of the present invention are directed to a porous medium screen that can be disposed in a wellbore through a fluid-producing formation. The porous medium screen can include a porous medium and a retaining structure. The porous medium can be a material having one or more pores. The pores can be adapted to allow a fluid to flow through the porous medium and to prevent particles from flowing through the porous medium. The retaining structure can be adapted to retain the porous medium in a position circumferentially surrounding a section of a tubing string and to prevent expansion of the porous medium. The retaining structure can include a shroud and one or more stoppers. The shroud can be adapted to circumferentially surround the porous medium. Each stopper can be adapted to circumferentially surround the section of a tubing string at an edge of the porous medium.

Abstract: The present invention relates to a crown-shaped separation device for separating oil and water in a well. Separator joints are sleeved on a central tube, and a separator is arranged between adjacent separator joints. Settlement cups are sleeved on the central tube, and two adjacent settlement cups are inserted together. A multi-rib separating bowl is embedded in the settlement cup. The settlement cup is crown shape. The bottom of the settlement cup is formed with multiple ribs. An angle is formed between the convex rib of the bottom of the settlement cup and the horizontal line. The top edge of the settlement cup is sawtooth shape corresponding to the shape of the cup bottom. An annular space is formed between the cup base of the settlement cup and the central tube. The central tube corresponding to the annular space is provided with a fluid inlet.

Abstract: A sacrificial liner linkage that can be used to automatically shorten a liner for an underground coal gasification process is provided. The sacrificial liner linkage may be one or more sacrificial liner linkage portions that are spaced between one or more liner portions in which the sacrificial liner linkage portions disintegrate before the one or more liner portions to automatically shorten the liner.

Abstract: Methods are provided for treating an oil reservoir to reduce the amount of sulfide in the production fluid obtained from a production well. The production fluid is treated with nitrate and/or nitrite ions, or another inorganic oxidizing agent, in an aqueous solution that is added to an injection well that is in contact with the production well.

Abstract: This invention provides for an apparatus that controls a liquid level down-hole of a hydrocarbon producing well by physically monitoring the liquid level down-hole having a down-hole liquid level measurer and a signal device connected to the liquid level measurer that causes a pump to adjust its current liquid output based on the liquid level down-hole as measured by the down-hole liquid level measurer.

Abstract: The use of a water recycle ratio for controlling at least one Steam Assisted Gravity Drainage (SAGD) parameter in a leaky bitumen reservoir. Further, a process to control a steam injection rate for an individual SAGD well pair, in a leaky bitumen reservoir wherein the process replaces a pressure control for an SAGD steam injection rate with a volume control determined by a Water Recycle Ratio (WRR).

Abstract: Systems and methods for monitoring a wellbore and actuating a downhole device include a body adapted for insertion into the wellbore that contains a processor, data storage, and sensors that detect a pressure, temperature, and acceleration associated with the body. Computer instructions are usable to receive and store preselected parameters, which include pressure, temperature, and acceleration ranges, and to compare measured values to these ranges for forming a determination usable to initiate actuation of a downhole tool. Additional parameters, such as temporal parameters, can be used to allow, cease, reset, or prevent actuation of the downhole tool.

Abstract: A method for automatically shortening an injection well liner for underground coal gasification is provided.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a petroleum bearing formation and petroleum and oil recovery formulation are produced from the formation. The produced oil recovery formulation is separated from the produced petroleum, and the produced oil recovery formulation is introduced into the formation.

Abstract: A gas generator is provided with a combustion chamber into which oxygen and a hydrogen containing fuel are directed for combustion therein. The gas generator also includes water inlets and an outlet for a steam and CO2 mixture generated within the gas generator. The steam and CO2 mixture can be used for various different processes, with some such processes resulting in recirculation of water from the processor back to the water inlets of the gas generator. In one process a hydrocarbon containing subterranean space is accessed by a well and the steam and CO2 mixture is directed into the well to enhance removability of hydrocarbons within the subterranean space. Fluids are then removed from the subterranean space include hydrocarbons and water, with a portion of the hydrocarbons then removed in a separator/recovery step. The resulting hydrocarbon removal system can operate with no polluting emissions and with no water requirements.

Abstract: One undeveloped alternative fuel is methane dissolved in ground water. Equipment for extracting methane from ground water is readily available. This Application presents a process to produce and use dissolved natural gas in the United States. The process includes the use of production wells, pumps, gas/water separators, compressors, low pressure gathering lines, and water disposal wells. Dissolved methane is present in virtually every basin now known to produce oil and dry gas. The Great Valley of California alone contains undeveloped dissolved methane resources of about 1,200 trillion cubic feet (TCF). Dry gas production in 150 years was about 10 TCF. The first full scale test of the extraction process was completed on Jul. 7-8, 2010 in California. Laboratory analyses of the gas produced showed that it was equal in heat value (about 940 to 975 BTU per cubic foot) to dry gas produced from the same field.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a petroleum bearing formation and petroleum is produced from the formation.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 vol. % dimethyl sulfide is introduced into a subterranean petroleum bearing formation and petroleum is produced from the formation.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a petroleum bearing formation, an oil immiscible formulation is introduced into the formation subsequent to introduction of the oil recovery formulation into the formation, and petroleum is produced from the formation.

Abstract: There are provided multi-stage methods for the enhanced recovery of high viscosity oil deposits from low temperature, shallow subterranean formations. The methods may include the steps of heating potentially extractable hydrocarbons, such as high viscosity oil, by injecting a sufficient amount of a heating fluid having a temperature and viscosity sufficiently high to minimize channeling and to permit penetration into regions of the reservoir containing the potentially extractable hydrocarbons. Thereafter, there is injected an extraction fluid that forms a mobile emulsion with the oil, without need for a co-solvent. The extraction fluid may include either a surfactant-polymer formulation or an alkaline-surfactant-polymer formulation. This is followed by injecting a polymer drive medium into the reservoir to displace and drive hydrocarbons and fluids comprising oil to a production well.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a subterranean petroleum bearing formation comprising heavy oil, extra heavy oil, or bitumen, and petroleum is produced from the formation.

Abstract: A method to operate a Steam Assisted Gravity Drainage with Oxygen (SAGDOX) process, in a leaky bitumen reservoir, wherein the process includes start-up, growth, decline and shut down phases. The start-up phase includes (1) Circulating steam in two horizontal (SAGD) wells, until communication is established between the two wells, (2) Injecting and optionally circulating steam in a SAGDOX oxygen injector well and vent gas well until communication is established, (3) Switching the wells to operate in a SAGD mode, with the upper well as a steam injector and the lower well as a fluid producer, creating a steam chamber, (4) Starting oxygen injection in the oxygen injector well, and (5) Opening at least one Produced Gas (PG) vent gas well, until steam injection is substantially limited to the upper well, oxygen injection has started and PG vent gas removal has started.

Abstract: A Single Well Steam Assisted Gravity Drainage (SWSAGD) process to recover liquid hydrocarbons from an underground hydrocarbon reservoir, wherein the single well includes a single substantially horizontal well including a heel area and a toe area, wherein the toe area of the horizontal well extends upwardly into the reservoir, the process including 1- injecting steam into the reservoir via a steam injection area, proximate the toe area of the horizontal well, 2- allowing the steam to condense causing heated hydrocarbon liquids and water to drain into a liquid recovery zone of the horizontal well between the toe area and the heel area of the horizontal well, and 3- recovering the heated hydrocarbon liquids to the ground surface from the liquid recovery zone.

Abstract: A treatment tool treats downhole features with one additive using sensors that acquire information relating to the downhole feature. A conveyance device selectively positions the treatment tool in a borehole. A related method includes acquiring information relating to the downhole feature using a treatment tool positioned in a borehole, estimating a condition relating to the downhole feature based on the acquired information, and treating the downhole feature using at least one additive applied by the treatment tool. The method may also include estimating a change in the condition of the downhole feature after the treatment of the downhole feature.

Abstract: Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer; the synthetic polymer being operative to increase the viscosity of the carrier fluid to about 5 to about 50 centipoise; the fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation.

Abstract: The invention provides for modified proppants, comprising a proppant particle and a hydrogel coating, wherein the hydrogel coating localizes on the surface of the proppant particle to produce the modified proppant, methods of manufacturing such proppants and methods of use.

Abstract: The present invention relates to the use of a composition for reinforcing cement, which comprises one or more compounds selected from group: a) sodium chloride, potassium chloride, magnesium chloride, calcium chloride, strontium chloride, barium chloride and ammonium chloride; b) aluminum chloride; and comprises one or more compounds selected from c) silica, zeolite, and apatite for cementing a wellbore. Moreover, the present invention relates to a cement slurry for cementing a wellbore, comprising I): cement; II) water; and III) a composition for reinforcing cement. In addition, the present invention relates to a method of cementing a wellbore.

Abstract: Set-delayed cement compositions and methods of using set-delayed cement compositions in subterranean formations. Embodiments include a method of drilling a wellbore in a subterranean formation comprising: circulating a drilling fluid comprising a set-delayed cement composition in the wellbore while drilling the wellbore, wherein the set-delayed cement composition comprises: pumice, hydrated lime, a set retarder, and water. A method of displacing a fluid in a wellbore comprising: introducing a spacer fluid comprising a set-delayed cement composition into a wellbore such that the spacer fluid displaces one or more prior fluids from the wellbore, and wherein the set-delayed cement composition comprises: pumice, hydrated lime, a set retarder, and water.

Abstract: Wellbore subassemblies usable to create a flowpath between a formation and a wellbore can include an inner sleeve and an outer sleeve positioned internal to and external of a core, the core having sockets containing charge assemblies. Upon actuation of the charge assemblies, the inner and outer sleeves are both simultaneously penetrated to form a fluid flowpath between the interior of the subassembly and the formation exterior to the subassembly. The structure of the subassembly can enable it to be lowed and used as part of a tubular conduit string both before and after perforation, the charge assemblies being unobtrusively embedded within the wall of the subassembly.

Abstract: A shear pig assembly and method of use for severing a linear conductor within a surrounding tubular. A shear pig assembly includes a main body and a nose that radially surround the linear conductor within the tubular. The main body and nose are axially moveable with respect to each other to cause a shear plug to move radially within a shearing chamber, thereby severing the linear conductor.

Abstract: Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; the synthetic polymer being operative to increase the viscosity of the carrier fluid to about 5 to about 50 centipoise; the fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation; and an oxidizing agent. A method for treating a hydrocarbon-bearing formation is also disclosed herein.

Abstract: Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; the polymer being crosslinked, the fracturing fluid having a viscosity of about 200 to about 3000 centipoise at 100 s?1; and an oxidizing agent. A method for treating a hydrocarbon-bearing formation is also disclosed herein.

Abstract: A method of transferring heat to or from a downhole element comprising contacting a downhole fluid comprising a fluid medium, and a nanoparticle, the nanoparticle being uniformly dispersed in the downhole fluid, to a downhole element inserted in a downhole environment. A method of cooling a downhole element, and a method of drilling a borehole are also disclosed.

Abstract: A method for fracturing a downhole formation, includes: preparing an energized fracturing fluid including mixing gaseous natural gas and a fracturing base fluid in a mixer; injecting the energized fracturing fluid through a wellhead and into a well; and continuing to inject the energized fracturing fluid until the formation is fractured. An apparatus for generating an energized fracturing fluid for use to fracture a downhole formation, the apparatus includes: a fracturing base fluid source; a natural gas source; and a mixer for accepting natural gas from the natural gas source and fracturing base fluid from the fracturing base fluid source and mixing the natural gas and the fracturing base fluid to generate the energized fracturing fluid.

Abstract: A drill pipe mountable wellbore cleaning tool apparatus is of an improved configuration that enables attachment to a drill pipe joint having first and second connector end portions and a cylindrically shaped portion in between the connector end portions. The drill pipe joint with attached debris cleaning tool or tools is made part of a drill string. The apparatus includes a support sleeve that is mounted to the drill pipe joint in between the connector end portions. The support sleeve abuts but does not invade the integrity of the cylindrical portion. Centralizers are attached to the opposing ends of the support sleeve, with each centralizer overlapping a portion of the support sleeve. The support sleeve carries one or more debris cleaning tools in between the centralizers. These tools enable debris to be removed from a wellbore. At least one locking clamp is attached to the cylindrical portion next to a said centralizer.