Abstract: A shunt system for a wellbore includes a first set of tubes defining a first plurality of fluid paths and a second set of tubes defining a second plurality of fluid paths. The shunt system also includes a mixing chamber positioned between the first set of tubes and the second set of tubes to allow slurry from the first plurality of fluid paths to mix together prior to outputting the slurry to the second set of tubes. Further, the shunt system is positionable external to one or more sand screens.

Abstract: A method for concurrent fluid injection and production of a reservoir fluid from a hydraulically fractured horizontal well comprising the steps of completing a well in a formation to create the hydraulically fractured horizontal well; designating an alpha group; designating a beta group, such that each segment is in either the alpha group or the beta group, wherein the number and location of the segments in each of the alpha group and the beta group are based on the production configuration; initiating a first mode of operation; operating the hydraulically fractured horizontal well in the first mode of operation for a first mode run time; stopping the first mode of operation; initiating the second mode of operation; operating the hydraulically fractured horizontal well in the second mode of operation for a second mode run time; and cycling between the first mode of operation and the second mode of operation.

Abstract: A flow control nozzle for regulating flow of fluid into a pipe comprises a body having a portion that is adapted to be received within an opening in the pipe, wherein the body includes a channel extending from an inlet to an outlet opening into the pipe. The channel includes a first section extending from the inlet and a second section extending to the outlet, wherein the first and second sections are connected at an elbow and wherein the first section has a constant cross-sectional area and the second section has a diverging cross-sectional area. An apparatus comprising the flow control nozzle and a base pipe and a screen.

Abstract: A high pressure fluid pump system of a fluid injection system includes a large volume displacement system, having a large volume pump, and low volume displacement system, having a low volume pump, a programmable logic control (PLC) computer coupled with each displacement system. The large volume displacement system is configured to incrementally or continuously increase a pressure of a fluid in a downhole to a predetermined pressure setting below a maximum pressure setting, and the low volume displacement system is configured to increase the pressure of the fluid from the predetermined pressure setting to a pressure setting above the predetermined pressure setting and at or below the maximum pressure setting. The functioning of the high pressure fluid pump system can be monitored, controlled and tested by the PLC computer. One or more graphical user interfaces can be coupled to the PLC computer for user input.

Abstract: Downhole gas separators, artificial lift systems including the downhole gas separators, hydrocarbon wells including the artificial lift systems, and methods of separating a gas from a liquid hydrocarbon within a hydrocarbon well. The downhole gas separators include an elongate outer housing that defines an enclosed volume, a fluid inlet port, and a gas outlet port. The downhole gas separators further include an elongate dip tube that extends within the enclosed volume, and the gas outlet port is configured to selectively provide fluid communication between the enclosed volume and an external region.

Abstract: A reservoir stimulation tool for stimulating a formation surrounding a wellbore having an inner wall includes: a tubular string including an outer wall defining therein an inner bore, the tubular string being configured to be inserted into the wellbore so as to form an annular space between the tubular string and the inner wall of the wellbore, a plurality of ports formed in the outer wall of the tubular string; a plurality of port valves for opening or closing the ports; and a plurality of packers coupled to the tubular string, wherein each packer is configured to be expanded in order to engage the inner wall of the wellbore, thereby isolating two or more longitudinal segments of the annular space from each other.

Abstract: An adjustable fluid injection tool for use in a wellbore may be used to provide steam to a wellbore annulus. The tool may be adjusted immediately before being positioned in a well. Fluid may exit an inner space of the tool into an accumulation chamber, after which the fluid may exit the tool through one or more adjustable valves. An adjustable valve may be formed between a valve seat of a shroud and a valve plug of a plug sleeve. The plug sleeve may be positioned around a tubular of the tool and able to translate linearly with respect to the shroud by rotating the plug sleeve, thus adjusting the adjustable valve and controlling fluid flow out of the tool.

Abstract: An apparatus for estimating an ambient environment at which inorganic scale will form in a downhole fluid includes a stress chamber disposed in a borehole in a production zone at a location within a specified range of maximum pressure and configured to receive a sample of the fluid from the production zone and to apply an ambient condition to the sample that causes the formation of inorganic scale. An inorganic scale sensor is configured to sense formation of inorganic scale within the chamber and an ambient environment sensor is configured to sense an ambient environment within the chamber at which the formation of inorganic scale occurs. The apparatus further includes a processor configured to receive measurement data from the inorganic scale sensor and the ambient environment sensor and to identify the ambient environment at which the formation of inorganic scale occurs.

Abstract: An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention is a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation. The controlled time delay enables casing integrity testing before fluid is passed through the ports. This time delay also allows multiple valves to be used in the same well casing and provide a focused jetting action to better penetrate a concrete casing lining.

Abstract: The present disclosure relates to delivery and release systems, such as core-shell particles. An exemplary composition according to the disclosure can include a carrier element forming an outer shell that defines an inner core. The core can include a reactive agent that is adapted to react with the shell, particularly at an inner interface of the shell with the core materials. The reaction can provide an inside-out degradation of the shell and release of one or more materials therein. The reactive agent may be separated from the shell, such as using a phase change material (PCM). Upon reaching specific environmental conditions, the PCM can change so as the release the reactive agent for reaction with the shell. The systems can be used in various methods to deliver a material to various environments, including underground reservoirs.

Abstract: A subterranean well fracturing system comprises a downhole well string having installed therein initially closed upstream and downstream sliding sleeve valve assemblies each openable to provide fracing fluid discharge outlets through well string side ports to an associated subterranean fracing zone. To inhibit an undesirable screen-out condition during formation fracturing, specially designed apparatus and methods are operative to sequentially (1) block the downstream valve seat, (2) open the blocked downstream valve seat using pressurized fracing fluid, (3) partially block the upstream valve seat, (4) open the partially blocked upstream valve seat using pressurized fracing fluid, a portion of which is flowed through the partially blocked upstream valve seat, and then (5) unblock the partially blocked upstream valve seat to permit a full flow of pressurized fracing fluid therethrough.

Abstract: A method and apparatus for selectively treating different zones in a wellbore includes running a tubular string into the wellbore, the string having at least two housings disposed therein, the housings separated along the string, each housing having a fluid path between an interior of the housing and a zone of interest and each housing having an individual profile for mating with an individual insert and running a second, smaller diameter tubular string into the wellbore, the string including an insert, the insert constructed and arranged to mate with a predetermined one of the plurality of housings and to initially seal the fluid path.

Abstract: A downhole fluid flow control system having dynamic response to local well conditions. The system includes a tubing string operably positionable in a wellbore. Annular barriers are positioned between the tubing string and the wellbore to isolate first and second zones. A fluid flow control device is positioned within each zone. A flow tube that is operably associated with the fluid flow control device of the first zone is operable to establish communication between the second zone and the fluid flow control device in the first zone such that a differential pressure between the first zone and the second zone is operable to actuate the fluid flow control device of the first zone from a first operating configuration to a second operating configuration.

Abstract: Systems and methods use enhanced flow control devices that can be selectively closed completely or have its effective flow area reduced to restrict production (or injection) by use of a chemical trigger mechanism. In addition, some of the systems deploy specific targeted chemical tracers, dissolvable in the unwanted production fluid (e.g., water or gas). These chemical tracers once dissolved will enter the production stream and be identified at the surface. An appropriate chemical trigger can be placed, for example, by pumping down through the tubing and utilizing intelligent completion valve to place the chemical, or by spotting with coiled tubing and bullhead to the formation. The chemical trigger will only trigger the active chemical in the appropriate flow control device.

Abstract: The invention includes systems and methods for operating, monitoring and controlling downhole fluid control system at a below ground location in a wellhole. The system may include a downhole fluid control system comprising at least one pump, a spoolable composite pipe comprising a fluid channel and at least one energy conductor, and a distal connection device adapted to couple a distal end of the fluid channel to the at least one pump and couple a distal end of the at least one energy conductor to the downhole fluid control system.

Abstract: An erosion resistant nozzle is brazed to the surface of a tubular, such as a shunt tube of a wellscreen apparatus, for use in a wellbore. The nozzle is elongated and defines an aperture for communicating exiting flow from the tubular's port. The lead end of the nozzle disposed downstream of the exiting flow can be lengthened to prevent erosion to the tubular. The lead endwall of the nozzle's aperture can be angled relative to the nozzle's length and can be rounded. The nozzle can be composed of an erosion resistant material or can be composed of a conventional material having an erosion resistant coating or plating thereon. Being elongated with a low height, the nozzle can have a low profile on the tubular, and the aperture's elongating can be increased or decreased to increase or decrease the flow area through the nozzle.

Abstract: The present disclosure describes a method for the recovery of hydrocarbons using a single horizontal well having both injection and production means. The well has a means for increasing fluid flow resistance in the wellbore. The injection and production means are operated so as to increase the fluid flow into the reservoir and reduce the fluid flow in the well. The means to increase fluid flow includes a constriction in the wellbore between the injection and production means, flow conditioners placed along a portion of the well between the injection and production means, and sealing elements placed in the well between the injection and production means. The production and injection openings are also positioned relative to the flow conditioners and sealing elements.

Abstract: Methods and systems of treating hydrocarbon containing formations are described herein. A system for treating a subterranean hydrocarbon containing formation includes a wellbore, and one or more packers positioned in the wellbore. At least one of the packers allows fluid to be injected in a subterranean hydrocarbon containing formation while allowing fluid to be produced from the wellbore.

Abstract: Methods and compositions including a method comprising: providing a treatment fluid comprising an aqueous fluid, a relative permeability modifier, and a chelating agent; introducing the treatment fluid into a well bore that penetrates a subterranean formation; and allowing at least a first portion of the treatment fluid to penetrate into a portion of the subterranean formation so as to substantially divert a second portion of the treatment fluid to another portion of the subterranean formation.

Abstract: A method for treating a production wellbore involves a moving liner run-in on a work string to a treatment zone. Treatment fluid is pumped at high flow rate and pressure down the annulus, through a crossover to the interior of the liner and to the treatment zone. Zones co-extensive with the liner are shielded from treatment as a path of least resistance is defined into the treatment zone. Relatively tight liner clearance and high treatment flow rates prevent treatment of shielded zones. Flow rate is reduced, but pressure maintained, while the moving liner is pulled, exposing another zone.

Abstract: An intrawell fluid injection system is operably positionable in a well having a production zone that is in fluid isolation from a discharge zone. The system includes an electric submersible pump assembly having an electric motor and a fluid pump that is operably associated with the electric motor. The fluid pump has a fluid intake operably positionable in fluid communication with the production zone. The fluid pump is operable to pump formation fluid from the production zone in a first axial direction. The system also includes a bypass assembly that is in downstream fluid communication with the electric submersible pump assembly. The bypass assembly is operable to transport formation fluid from the electric submersible pump assembly in a second axial direction that is opposite the first axial direction. The bypass assembly has a fluid discharge operably positionable in fluid communication with the discharge zone.

Abstract: A technique provides a system and methodology for treating a plurality of zones, e.g. well zones. A plurality of flow control devices is located along a tubular structure, such as a well string in a wellbore. Each flow control device or each set of flow control devices comprises a seat member having a unique profile relative to the profiles of the other flow control devices. Drop objects are designed with engagement features arranged to engage the profiles of specific flow control devices. For example, each drop object may have an engagement feature of a corresponding profile designed to engage the unique profile of a specific flow control device or of a specific set of flow control devices to enable actuation of the specific flow control device or the specific set of flow control devices once the drop object is dropped through the tubular structure.

Abstract: A system for and methods of producing hydrocarbons from a formation. A method may include drilling a wellbore in a formation, forming a first fracture in the formation that emanates from the wellbore, forming a second fracture in the formation that emanates from the wellbore and is approximately parallel to the first fracture, and simultaneously (a) injecting a fluid from an injection tubing string in communication with the second fracture and (b) producing hydrocarbons that travel from the first fracture into a production tubing string that is substantially parallel to the injection tubing string. The wellbore may be substantially horizontal. The fluid may increase pressure in an area of the formation adjacent to the first fracture.

Abstract: Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies.

Abstract: A downhole fluid flow control system having dynamic response to local well conditions. The system includes a tubing string operably positionable in a wellbore. Annular barriers are positioned between the tubing string and the wellbore to isolate first and second zones. A fluid flow control device is positioned within each zone. A flow tube that is operably associated with the fluid flow control device of the first zone is operable to establish communication between the second zone and the fluid flow control device in the first zone such that a differential pressure between the first zone and the second zone is operable to actuate the fluid flow control device of the first zone from a first operating configuration to a second operating configuration.

Abstract: A remediation process that a employs improved quantitative method(s) of estimating of the volume and/or mass of contaminant in the subsurface, removal and or in situ degradation of the contamination using subsurface pulsing treatment (“SPT”) technology, and evaluation of the degree of remediation by re-applying the quantitative contaminant evaluation methods. The process uses SPT technology with the addition of a vacuum or sub-atmospheric pressure to an extraction well in order to create a push-pull effect to remove free contaminant or residual in conjunction with the pressure wave driving force created in the excitation or excitation well. The process can quantitatively measure the amount of residual contaminant, which up until now has not been possible or tractable using in situ methods, as well as measure the amount of residual that can be removed by SPT.

Abstract: A tool for selectively treating a wellbore with fluid that includes a tubing string having a sidewall defining an inner bore, the sidewall comprising a flow area having at least one fluid flow port that permits fluid flow through the sidewall. Fluid is prevented from flowing through the flow area when a closure is in a closed position. When in the open position, fluid flows through the flow area. An axial seal is connected to the closure to selectively close the inner bore against fluid pressure to apply the predetermined opening force to move the closure to the open position. A releasable connector connects the axial seal to the closure and a retrieval tool attachment releases the axial seal from the closure upon application of a predetermined release force by a retrieval tool.

Abstract: A downhole fluid flow control system having dynamic response to local well conditions. The system includes a tubing string operably positionable in a wellbore. Annular barriers are positioned between the tubing string and the wellbore to isolate first and second zones. A fluid flow control device is positioned within each zone. A flow tube that is operably associated with the fluid flow control device of the first zone is operable to establish communication between the second zone and the fluid flow control device in the first zone such that a differential pressure between the first zone and the second zone is operable to actuate the fluid flow control device of the first zone from a first operating configuration to a second operating configuration.

Abstract: A method of inducing fracture complexity within a fracturing interval of a subterranean formation is provided. The method comprises defining a stress anisotropy-altering dimension, providing a straddle-packer assembly to alter a stress anisotropy of a fracturing interval, based on defining the stress anisotropy-altering dimension, isolating a first fracturing interval of the subterranean formation with the straddle-packer assembly, inducing a fracture in the first fracturing interval, isolating a second fracturing interval of the subterranean formation with the straddle-packer assembly, inducing a fracture in the second fracturing interval, wherein fracturing the first and second fracturing intervals alters the stress anisotropy within a third fracturing interval, isolating the third fracturing interval with the straddle-packer assembly, and inducing a fracture in the third fracturing interval.

Abstract: A downhole tool is provided that selectively opens and closes an axial/lateral bore of a tubular string positioned in a wellbore used to produce hydrocarbons or other fluids. When integrated into a tubular string, the downhole tool allows individual producing zones within a wellbore to be isolated between stimulation stages while simultaneously allowing a selected formation to be accessed. The downhole tools and methods can be used in vertical or directional wells, and additionally in cased or open-hole wellbores.

Abstract: Devices, systems and related methods control a flow of a fluid between a wellbore tubular and a formation using a flow control device having a flow space formed therein; and a flow control element positioned in flow space. The flow control element may be configured to flex between a first radial position and a second radial position to in response to a pressure differential along the flow space.

Abstract: A method of producing oil which begins by drilling, casing and inserting a tubing string in a wellbore. The method then perforates both an upper portion and a lower portion of the casing to establish communication between the wellbore with a upper horizontal fracture and a lower horizontal fracture. A retrievable packer or a seal assembly is inserted horizontally between the tubing string and the casing and vertically between the upper horizontal fracture and the lower horizontal fracture for heat isolation. Steam is then injected into the wellbore both into the upper horizontal fracture and the lower horizontal fracture. Heavy oil is then produced from the lower horizontal fracture while injecting steam into the upper horizontal fracture.

Abstract: A method for enhancing the storage of carbon dioxide underground. The method comprises locating a geological formation comprising a first storage reservoir having a first surface and a second surface, a first seal layer adjacent the first surface of the first storage reservoir, a second seal layer adjacent the second surface of the first storage reservoir, and a second storage reservoir adjacent the first seal layer opposite the first storage reservoir; directing carbon dioxide into the first storage reservoir, the carbon dioxide being at a first pressure within the first storage reservoir; directing a fluid into the second storage reservoir, the fluid being at a second pressure within the second storage reservoir; and maintaining the second pressure at generally the same or larger pressure than the first pressure of the carbon dioxide to reduce leakage of CO2.

Abstract: Methods and systems for gas sequestration are provided. The systems include a porous storage reservoir containing a dense fluid; a first tubing string, configured to provide and inject a gaseous emissions (GE) stream at or near the top of the porous storage reservoir above the base portion of the porous storage reservoir; and a second tubing string configured to withdraw the dense fluid from the base portion of the porous storage reservoir. In some embodiments, the first and second tubing strings may be encased in a single well bore and may include measurement and control equipment for pressure management of the injection locations. The withdrawn dense fluids may be re-injected into an overlying porous reservoir or may be sent to the surface for treatment. Methods are provided for injection of GE and withdrawal of dense fluids for safe, long term gaseous sequestration of significant portions of carbon dioxide (CO2) and associated gases (gaseous emissions, GE).

Abstract: A system and process for extracting geothermal energy from a geologic formation. Coolant fluid is introduced into a first fracture system. The first fracture system is at a first height in the formation. The coolant fluid is collected from a second fracture system. The second fracture system is at a second height in the fracture system. The second height is lower than the first height. Coolant fluid introduced into the first fracture system percolates through the geologic formation from the first fracture system to the second fracture system, collecting heat from the geologic formation.

Abstract: An intelligent completion system includes production tubing configured for production from multiple zones in a wellbore. At least one flow control valve is disposed on the production tubing for each of the multiple zones, this flow control valve capable to regulate the flow of a wellbore fluid into the production tubing. A chemical injection mandrel is disposed on the production tubing adjacent the at least one flow control valve in the each of the multiple zones, this mandrel being connected to at least one chemical injection line for injecting one or more chemicals into the wellbore. A control mechanism is connected to the at least one flow control valve and the chemical injection mandrel such that the injection mandrel and the at least one flow control valve are operated in a coordinated manner.

Abstract: A property of fluid within a well in a geological volume is controlled. The property of the fluid may include fluid density, pressure gradient, temperature, foaming characteristics, and/or other fluid properties within the well. In particular, the fluid property is controlled discretely within different sections (e.g., at different depths) of the well.

Abstract: A method and apparatus is provided for diverting a ground water supply source located in a stratum that is hydraulically separated from a hydrocarbon-containing reservoir formation for injection into the reservoir proximate the oil-water interface to enhance the flow rate and production of the hydrocarbons through one or more well bores without pumping the injection water to the earth's surface. An electric submersible pump (ESP) and Y-tool assembly is positioned in the well bore at the level of the ground water supply and water is pumped down the well casing for injection into the formation, e.g., below the hydrocarbon-containing reservoir rock. Suitable seals, packers and cement plugs are provided to isolate the high pressure injection water from the ground water drawn into the first upper portion of the casing.

Abstract: Described embodiments relate to methods, systems and infrastructure for flow manipulation within a porous volume. Some embodiments relate to a method of subsurface flow manipulation, comprising: providing fluid at a first subsurface location adjacent to or in a subsurface volume through which the fluid is to pass; providing first suction at a second subsurface location adjacent to or in the subsurface volume to extract fluid from the subsurface volume, the second subsurface location being located across at least part of the subsurface volume from the first subsurface location; providing fluid at a third subsurface location spaced from the first subsurface location and adjacent to or in the subsurface volume; and providing second suction at the first, second or a fourth subsurface location adjacent to the subsurface volume to extract fluid from the subsurface volume.

Abstract: A wellbore servicing system, comprising a first sleeve system, the first sleeve system comprising a first sliding sleeve at least partially carried within a first ported case, the first sleeve system being selectively restricted from movement relative to the first ported case by a first restrictor while the first restrictor is enabled, and a first delay system configured to selectively restrict movement of the first sliding sleeve relative to the ported case while the restrictor is disabled.

Abstract: A system for and method of supplying an injection fluid to a well assembly so that the injection fluid flows at a substantially constant flow rate. The fluid can be injected at a single site in the well assembly or multiple sites. A flow control regulator is included that attaches to the well assembly and provides a self adjusting flow control for the fluid being injected. The regulator includes a slidable floating sleeve having an orifice through which the fluid flows. The sleeve includes an inlet port that can register with a fluid supply port to allow the injection fluid to make its way into the sleeve. The fluid exits the sleeve through the orifice to generate a pressure differential across the orifice that in turn exerts a sliding force onto the sleeve. Moving the sleeve misaligns the inlet port and fluid supply port thereby throttling flow through the regulator to a predetermined flow rate.

Abstract: A novel method is provided for in situ combustion and recovery of oil from underground reservoirs including injecting oxygen into the reservoir at a region near the reservoir floor, establishing a combustion front wherein hot combustion gases rise at the combustion front, withdrawing hot combustion gases from a region near the reservoir ceiling, and extracting oil from a horizontal production well near the reservoir floor.

Abstract: A remediation system for decontaminating a polluted site that delivers a remediation fluid to the polluted site and receives a contaminated effluent from the polluted site. The system includes a reactor that receives the contaminated effluent and generates an exit fluid stream and a first flow control mechanism coupled to the outlet of the reactor that releases a controlled portion of the exit fluid from the system, and delivers the remaining portion of the exit fluid as the remediation fluid, or delivers the remaining portion to a second flow control mechanism for combination with a controlled quantity of the second reactant to form the remediation fluid.

Abstract: A method of lowering the temperature of a subsurface formation, e.g., comprising oil shale, includes injecting a cooling fluid under pressure into a wellbore. The wellbore is completed at or below a depth of the subsurface formation, and the wellbore includes a bore formed through the subsurface formation defining a diameter. The cooling fluid comprises a slurry having particles of frozen material. The cooling fluid is circulated across the formation in order to lower the temperature of at least a portion of the formation to a point that is at or below the freezing point of water.

Abstract: A fluid conveyable device having an interior space receives a payload that may be transported along at least a section of a borehole. The device includes a access control member for conveying the payload between the interior and the exterior of the fluid conveyable device.

Abstract: The present invention provides drilling fluids that comprise a base fluid and a water-soluble relative permeability modifier. In addition, the present invention provides methods of reducing the permeability of a subterranean formation to aqueous-based fluids during the drilling phase that comprises providing a water-soluble relative permeability modifier; and placing the water-soluble relative permeability modifier into the subterranean formation during the drilling phase. The present invention provides methods of drilling a well bore in a subterranean formation comprising providing a drilling fluid that comprises a base fluid and a water-soluble relative permeability modifier, and placing the drilling fluid in the subterranean formation. The water-soluble relative permeability modifiers of the present invention generally may comprise hydrophilically modified polymers, hydrophobically modified polymers, or water-soluble polymers without hydrophobic or hydrophilic modification.

Abstract: The invention relates to cleaning wellbores and the near wellbore areas adjacent to a hydrocarbon bearing formations and coal bed methane formations. In a particular aspect, the invention relates to removing liquids such as water and/or oil from the formation near the wellbore. The cleaning and liquid removal is accomplished with liquid carbon dioxide or a treatment medium that includes liquid carbon dioxide. The treatment medium is injected into the wellbore through tubing in a controlled manner so that the treatment medium enters the formation in a liquid state, although a portion may be allowed to vaporize upon introduction into the wellbore. The treatment medium is then allowed to vaporize and loosen and entrain undesirable materials from the formation and from within the wellbore or casing, and mobilize water and oil present by effervescing and by dissolving.

Abstract: An acid treatment composition is provided including a corrosion inhibitor and an optional corrosion inhibitor intensifier in an acidic solution. More specifically, the composition includes an anionic surfactant. Methods for treating wells with these acid treatment compositions are also provided that help control corrosion of the steel used in the wells during the acid treatment.

Abstract: A geothermal system in deep, hot, dry rock has closed loop circulation, in which the water and steam circulating in the system are protected from any direct contact with the base rock. The system has a single L-shaped bore with a casing that lines the wellbore and has a sealed bottom end. A tubing within the casing has an open bottom end. Water or other liquid or gas is injected under pressure into the casing in the space between the casing and the tubing and is heated by the deep hot rock strata, creating heated liquid or gas which flows into the tubing through its open bottom end and is returned to the surface for use for heating, or in a power plant, or other applications. In a reverse configuration, the working fluid is injected into the tubing and is returned via the space between the casing and the tubing.

Abstract: A technique facilitates a water flood, e.g. dump flood, operation. A standard electric submersible pumping system is deployed in a wellbore to draw water from an aquifer or water source zone along the wellbore. A shroud and a crossover port are used in combination with the submersible pumping system to redirect pumped water downwardly along an isolated flow path. The downward flow of pumped water is directed along the wellbore and injected into a desired, injection zone to facilitate recovery of oil or to perform other types of water flood operations.