Abstract: A device for controlling injection of treatment fluids in plunger lift systems includes a lubricator cap coupleable to a lubricator. The lubricator cap defines a fluid inlet coupleable to a fluid injection system. A sensor coupled to the lubricator cap detects arrival of a plunger within the lubricator a controller communicatively coupled to the sensor transmits an indicator corresponding to arrival of plunger to a fluid injection control system. In response, the fluid injection system injects fluid into the fluid inlet to recharge the plunger. In certain implementations, the sensor detects arrival of the plunger at the lubricator by detecting movement of a lubricator spring or a component of a lubricator spring, such as a spring follower.

Abstract: A method comprises operating a first valve arrangement and a second valve arrangement from a locked first configuration, in which the first port is closed and the second port is closed, to a locked second configuration, in which the first port is open and the second port is closed. The method comprises operating the first valve arrangement and the second valve arrangement from the locked second configuration to a third configuration, in which the first port is closed and the second port is open; and moving the first valve arrangement to a third intermediate configuration between a second intermediate configuration and the third configuration, in which the first valve arrangement is locked, the second valve arrangement is locked and the first and second ports are closed.

Abstract: An apparatus, system, and method are provided for injecting carrier sleeves into a wellbore. The injection system is capable of individually indexing a selected sleeve from a sleeve magazine into an injector bore and axially aligning the sleeve with the bore with a retaining device. The retaining device prevents a subsequent sleeve from being indexed into the bore from the magazine. The selected sleeve can be restricted from free fall using a staging mechanism, which can subsequently be opened to permit the selected sleeve to fall into a staging bore. The staging bore is then fluidly isolated from the injector bore and the wellbore, pressure in the staging bore is equalized with the wellbore, and then opened to the wellbore for injecting the sleeve into the wellbore. The sleeve can be axially aligned and radially centered with the injector bore using a tapered portion in the bore or the staging mechanism.

Abstract: Deployable smart acoustic resonance particles have dense cores, compliant matrixes surrounding the cores and stiff outer shells surrounding the matrixes. The particles have mechanical stress sensitivities that provide unique band gap shifts when compressed. Groups of similar particles with similar stress sensitivities and similar band gap shifts are added at different times to hydraulic fluids, as circulated through wells with the fluid and pushed into fractures. A plural, sonic monopole well logging tool is lowered into the well to determine locations and depth of fractures and local pressures by distinct resonance of individual groups.

Abstract: Aqueous well treatment fluids especially suited for use in far field diversion in low viscosity carrier fluids comprise water, a friction reducer, and a diverter. The diverter comprises dissolvable particulates and proppants. The dissolvable particulates have a specific gravity of from about 0.9 to about 1.6 and a particle size of about 50 mesh or less. The proppants have a specific gravity of from about 0.9 to about 1.4 and a particle size of from about 20 to about 100 mesh. The dissolvable particulates have a higher specific gravity and a smaller particle size than the proppant.

Abstract: A bypass plunger includes a plunger body that includes a head portion located at one end of the plunger body and a tail portion located at an opposite end of the plunger body. The head portion includes at least one flow port, and the tail portion includes at least one passageway. A valve component is disposed within an internal bore of the plunger body and is moveable between an open position and a closed position. At least one plug is located within a respective one of the flow ports and/or a respective one of the passageways, and is configured to reduce or prevent flow through the respective flow port or the respective passageway.

Abstract: Treating carbon steel tubing includes contacting the carbon steel tubing with a first treatment solution including a salt; corroding the carbon steel tubing with the salt to yield a corroded surface on the carbon steel tubing; contacting the corroded surface on the carbon steel tubing with a second treatment solution comprising sulfide ions; and forming an iron sulfide layer on the corroded surface of the carbon steel tubing by chemically bonding the sulfide ions in the second treatment solution with iron in the carbon steel tubing. In some cases, the first treatment solution also includes sulfide ions, and the iron sulfide layer is formed by contacting the carbon steel tubing with the first treatment solution.

Abstract: Provided is a safety valve. The safety valve, in one example, includes a piston located within a piston chamber, the piston separating the piston chamber into a first portion and a second portion and configured to slide to move a valve closure mechanism between a closed state and an open state. The safety valve, according to this example, includes a first control/balance line fluidically coupled to the first portion of the piston chamber, a second control/balance line fluidically coupled to the second portion of the piston chamber, and a chemical line fluidically coupled to the second control/balance line.

Abstract: An apparatus, system, and method are provided for injecting carrier sleeves into a wellbore. The injection system is capable of individually indexing a selected sleeve from a sleeve magazine into an injector bore and axially aligning the sleeve with the bore with a retaining device. The retaining device prevents a subsequent sleeve from being indexed into the bore from the magazine. The selected sleeve can be restricted from free fall using a staging mechanism, which can subsequently be opened to permit the selected sleeve to fall into a staging bore. The staging bore is then fluidly isolated from the injector bore and the wellbore, pressure in the staging bore is equalized with the wellbore, and then opened to the wellbore for injecting the sleeve into the wellbore. The sleeve can be axially aligned and radially centered with the injector bore using a tapered portion in the bore or the staging mechanism.

Abstract: Packaging structures and systems are used for handling components for use in a nuclear reactor. The packaging protects the component during transport and handling and then dissolves in liquid in the nuclear reactor or fuel pool. The packaging need not be removed and may block flow paths or otherwise interfere with operability were it not for its dissolution. The packaging may include shock absorbers in a fuel assembly or a seal on a water rod in the assembly. Mechanical, frictional, or chemical retaining materials may be used to secure the packaging and may also dissolve in the liquid. For a light water reactor, polymers, protein gels, and plastics can all be used where they will dissolve in the water and are otherwise compatible with reactor chemistry and neutronics. Materials with higher temperatures for solubility may be used because they will dissolve when reactor operations commence.

Abstract: A universal atmospheric deployment device (“UADD”) for use in oil and gas production or similar applications is provided. In one embodiment, the UADD includes a number of storage carriers disposed around a pathway that can be deployed into a well bore. The figures and art described herein show that this novel feature can increase the speed and usefulness of dispatching tools down a well bore, and also decrease down time to install or retrieve these devices. This UADD also removes personnel from the hazardous area, allowing for remote deployment of tools and devices.

Abstract: A sealing tool for sealing a tubing string at a predetermined location, the sealing tool having a prong assembly and a plug assembly, each of which includes a cavity configured to capture and retain debris, and the plug assembly including at least one equalization hole for fluid communication through the plug when unobstructed by the prong.

Abstract: Systems and methods having friction reducer compositions for use in subterranean treatment fluids are presented. An embodiment is a method comprising: (A) forming a treatment fluid comprising: an aqueous base fluid, a friction reducer, and an alkaline buffering agent, wherein the treatment fluid has a pH in the range of about 7 to about 10; and (B) injecting the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation.

Abstract: Embodiments of the present disclosure are directed to a method of producing a viscoelastic surfactant (VES) fluid, the VES fluid comprising desulfated seawater. The method of producing the VES fluid comprises adding an alkaline earth metal halide to seawater to produce a sulfate precipitate. The method further comprises removing the sulfate precipitate to produce the desulfated water. The method further comprises adding a VES and one or more of a nanoparticle viscosity modifier or a polymeric modifier to the desulfated seawater. Other embodiments are directed to VES fluids that maintain a viscosity greater than 10 cP at temperatures above 250° F.

Abstract: A method for operating in a borehole penetrating a formation is disclosed. The method includes disposing in the borehole an assembly comprising a load-bearing and oil-disintegrable tool comprising a polymeric composite; performing a downhole operation; and disintegrating the load-bearing and oil-disintegrable tool with a hydrocarbon fluid. The polymeric composite comprises an oil-disintegrable polymer which is one or more of the following: a polydicyclopentadiene, polypropylene, polyurethane, polycarbonate, polysulfone, or a high density polyethylene, the polyurethane being a polyhedral oligomeric silsesquioxane-modified polyurethane, a lauryl methacrylate graft polyurethane copolymer, a divinylbenzene crosslinked polyurethane, or a combination comprising at least one of the foregoing.

Abstract: An apparatus for controlling fluid flow in a wellbore may include a valve disposed along a drill string. The valve includes a valve body having an internal chamber, a plurality of ports formed in the valve body, a ball disposed in the internal chamber, and an actuator operatively connected to the ball. The ball includes at least one flow bore. The actuator shifts the ball into at least a first position wherein the flow bore is in fluid communication with at least two of the plurality of ports, and a second position wherein the flow bore is isolated from at least one of the plurality of ports. A related method includes conveying a drill string having the above-described valve along the wellbore and controlling a flow of fluid by shifting the ball using the actuator.

Abstract: Systems, methods and apparatus for injecting a solid chemical for inhibiting, decreasing or preventing precipitation and/or deposition of foulants and/or contaminants in oilfield tubulars. The use of solid chemicals or highly viscous fluids providing ease of shipment, greater economy in storage, shipment and delivery and increased ease of use.

Abstract: An automated wash system for use with a progressing cavity (PC) pump system. The automated wash system includes a wash fluid source and a wash valve. The wash valve is in fluid communication with the wash fluid source and an annulus of a well casing of the PC pump system and is operably coupled to the controller. Upon receipt of a command to initiate a wash cycle, the controller opens the wash valve to enable wash fluid to be directed into the annulus and increases a speed of a PC pump of the PC pump system to effect cleaning of the well casing.

Abstract: Systems, methods and apparatus for injecting a diluted solid chemical, a diluted highly viscous fluid, or a diluted fluidified solid for inhibiting, decreasing or preventing precipitation and/or deposition of foulants and/or contaminants in oilfield tubulars. The use of solid chemicals or highly viscous fluids providing ease of shipment, greater economy in storage, shipment and delivery and increased ease of use.

Abstract: A chemical injection pump is installed below an electric submersible pump. In general, the chemical injection pump is either driven by an electric motor that draws power from the electric submersible pump motor or from energized fluid leaving the electric submersible pump output port. The electric submersible pump provides electric or hydraulic power to run the chemical injection pump.

Abstract: A chemical injection pump is installed below an electric submersible pump. In general, the chemical injection pump is either driven by an electric motor that draws power from the electric submersible pump motor or from energized fluid leaving the electric submersible pump output port. The electric submersible pump provides electric or hydraulic power to run the chemical injection pump.

Abstract: Embodiments of the present disclosure are directed to double emulsified acids, specifically water in oil in water (W/O/W) double emulsions with an acidic interior water phase. The double emulsified acid may include two or more emulsifying agents. In addition to improving the stability of the emulsions, the emulsifying agents may help slow the acid reaction rate. The first emulsifying agent may have an HLB greater than 7 and the second emulsifying agent may have an HLB less than or equal to 7. Other embodiments are directed to methods for producing a double emulsified acid and methods for acidizing a carbonate formation including a double emulsified acid.

Abstract: A ball launcher for launching a plurality of balls into a well, including an endless conveyor belt, the conveyor belt forming a plurality of ball retainers, each operable to contain one of the plurality of balls, a drive motor for selectively driving the conveyor belt, and a brake for braking the conveyor belt.

Abstract: A drug dosing device and method for dosage metering and control, the drug dosing device including a drug dosing canister, a first flow channel, a second flow channel, a third flow channel, a metering flow channel, a switch valve, a control valve and a pressure release port; the upper part or top of the drug dosing canister communicates with the upper part or top of the metering flow channel via the first flow channel; the lower part or bottom of the drug dosing canister communicates with the lower part or bottom of the metering flow channel via the second flow channel; the switch valve disposed on the second flow channel; the bottom or lower part of the metering flow channel communicates with the control valve via the third flow channel; the pressure release port is disposed at the upper part or top of the drug dosing canister; and the cross section area of the metering flow channel is less than the cross section area of the drug dosing canister.

Abstract: A well tool includes a body defining an enclosed fluid passage. A bipolar electrode is provided in the well tool, changeable between a first, energized state, and a second, different state. The bipolar electrode in the first state produces an ion depletion zone that presents a flow restriction to saline fluids in the fluid passage.

Abstract: Provided is a chemical injection pump that is installed below an electric submersible pump. In general, the chemical injection pump is either driven by an electric motor that draws power from the electric submersible pump motor or from energized fluid leaving the electric submersible pump output port. The electric submersible pump provides electric or hydraulic power to run the chemical injection pump. Therefore, no surface chemical injection pump is required and hence less space is needed.

Abstract: A well cementing method includes combining a spacer polymer with a liquid in a first mixer and producing a spacer polymer blend yielding a spacer pumped into a well using a product pump. The method includes combining a cement additive with the liquid in the first mixer and producing a cement additive blend yielding a wellbore cement pumped into the well following the spacer using the product pump. Another well cementing method includes combining a cement additive with a liquid in a first mixer and producing a cement additive blend. The method combines bulk cement materials and the cement additive blend in a second mixer and produces a wellbore cement pumped into a well. A well cementing system includes a liquid pump, a first mixer, an additive feeder, a second mixer separate from the first mixer, a cement feeder, and a product pump.

Abstract: An electrical submersible pump assembly has pump, motor and pressure equalizer modules. A first adapter, which secures to the first module, has an external set of first adapter threads. A second adapter, which secures to the second module, has an external set of second adapter threads. A collar has an internal set of collar first threads that engage the first adapter threads, and an internal set of collar second threads that engage the second adapter threads. The collar first and second threads differ from each other, such that rotation of the collar relative to the first and second modules pulls the first and second modules toward each other. The pitches of the collar first and second threads may differ. Or, the collar first and second threads may turn in opposite directions.

Abstract: The invention is directed to delayed gelation agents comprising a degradable polymeric cage containing therein one or more gelation agents. The cage degrades in situ, e.g, in an oil reservoir, thus releasing the gelation agent(s), which can then crosslink second polymers in situ to form a gel.

Abstract: A method for inhibiting scale including inorganic cations, and an economically operable geothermal power generating device which can inhibit deposition of scale. The geothermal power generating device includes: an inorganic cation concentration measuring device for measuring the concentration of bivalent or more inorganic cations in geothermal water collected from a production well; a flowmeter for measuring the flow rate of the geothermal water collected from the production well; a heat removal unit for lowering the temperature of the geothermal water; a thermometer for measuring the temperature of the geothermal water after removing heat; a pH measuring device for measuring the pH of the geothermal water after removing heat; a calculation processing unit for calculating the additive amount of a scale inhibitor; and a control unit for adding the scale inhibitor to the geothermal water by the amount calculated by the calculation processing unit.

Abstract: A compression test rig apparatus for determining a mechanical characterization of a gel-based LCM test sample comprising an LCM test cell configured to contain the gel-based LCM test sample, the LCM test cell comprising a cylinder wall defining a cell space volume configured to hold the gel-based LCM test sample, and a floor defining an extrusion hole configured to extrude the gel-based LCM test sample to create an extruded gel; an extruded gel collector configured to receive the extruded gel from the extrusion hole as an extruded gel volume; a perforated disc comprising perforations, wherein the perforated disc is configured to allow the gel-based LCM test sample to pass through the perforations; and a flat foot disc piston in flush contact with the cylinder wall, the flat foot disc piston configured to compress the gel-based LCM test sample at a displacement speed to produce compression data.

Abstract: A gas-lift plunger includes a body having an upper end, a lower end, a bore extending axially from the upper end to the lower end, and a port therein that is in communication with bore, and an obstructing member positioned in the bore. The obstructing member includes a valve stem and is movable between a closed position, in which the obstructing member substantially prevents fluid flow through the bore from the port to the upper end, and an open position, in which fluid flow through the bore from the port to the upper end is permitted. The plunger includes an end nut connected to the lower end of the body, and a clutch assembly including arcuate members that are positioned at least partially around and configured to engage the valve stem to impede movement thereof. The clutch assembly is positioned at least partially within the end nut.

Abstract: A control system for a Subsurface Safety Valve (SSSV), includes an actuating piston mounted in a housing with at least one seal and connected to the SSSV. The actuating piston having a first end and a second end, the first end in fluid communication with a control line; a primary pressure reservoir in fluid communication with the second end of the actuating piston, the reservoir configured to contain a fluid under an amount of pressure selected to act against a prospective hydrostatic pressure expected in the control line based upon the selected position of the control system in a downhole environment.

Abstract: Embodiments of the present disclosure are directed towards functionalized oligomers. As an example, a functionalized oligomer can be represented of Formula (I): (Formula I) in which R1 is a structure of Formula II: (Formula II) and R2 has a formula —CxHyO—, wherein n is an integer having a value from 2 to 6, m is an integer having a value from 2 to 10, X independently is an integer having a value from 1 to 12, and Y is an integer having a value from 2 to 24.

Abstract: A method of reducing silicosis caused by inhalation of silica-containing proppant, such as silica sand and resin-coated silica sand, and apparatus therefor.

Abstract: A hydraulic system includes a chemical injection line and a plurality of tools in operable communication with the chemical injection line that are independently responsive to changes in pressure or flow through the chemical injection line and that are configured to control flow of wellbore fluids.

Abstract: Systems and processes are provided for removing fluid from a subterranean well and enhancing the production of oil and/or gas are herein disclosed. In one embodiment, the system includes an injection conduit, an injection valve, a relief valve, a container, a container valve, a return conduit valve, and a return conduit, all arranged within a subterranean well for removing at least one fluid from the well. The removal of at least one fluid from the well is controlled by the flow of gas into the injection conduit.

Abstract: The present disclosure provides methods of using a nonionic surfactant for enhanced oil recovery, where the nonionic surfactant is prepared with a double metal cyanide catalyst. The present disclosure also provides for an emulsion that includes carbon dioxide, a diluent and the nonionic surfactant.

Abstract: An apparatus and method for determining a concentration of an additive in a mixture is provided. The apparatus for determining the concentration of an additive in a mixture comprises a distillation system, a filtration system, a detection system and a fluid transportation system. An alternative apparatus is a portable apparatus comprising a distillation system, a filtration system, a detection system and a fluid transportation system removably coupled to a portable container. A method for determining the concentration of the additive in the mixture includes concentrating the additive in the mixture, removing the additive from a fraction of the mixture and measuring a spectral signature of both the non-additive fraction of the mixture and the mixture. A spectral signature value of the non-additive fraction of the mixture to the mixture is determined and then compared to spectral signatures of a plurality of reference mixtures containing known concentrations of the additive.

Abstract: A method for delivering a chemical composition downhole into a wellbore includes forming a cylindrical body including a treatment chemical, where the cylindrical body includes a flow channel therethrough. The method further includes positioning the cylindrical body into a fluid conduit of a wellbore, and flowing a release fluid through the flow channel to release at least part of the treatment chemical into the release fluid. The release fluid causes the release of the treatment chemical by dissolving the chemical, and/or by removing a coating on the chemical through dissolution, response to pH adjustment, and/or response to an abrasive material in the release fluid. Examples of a treatment chemical include a cross-linker, breaker, fluid loss pill agent, and an encapsulated chemical.

Abstract: The present invention relates to a method for recovering methane gas from natural gas hydrates. In particular, it includes the step of adding a gas mixture containing air and carbon dioxide to an NGH of deep sea and the step of replacing the methane gas with gas mixture and the step of decomposition-replacement of methane hydrate. In accordance with the present invention, the invention is possible use as a technique for recovery of methane gas in the all-weather to induce replacement reaction using a gas mixture when the temperature of the technology applied is low and to induce degradation of solid methane hydrate by mixing gas when the temperature of the region technique is applied is high. Further, the method makes it possible to reduce costs than using conventional methods because the air is collected directly from the NGH reservoirs and compressed and is injected as a mixture with carbon dioxide and, there is no need to transport the infusion another gas.

Abstract: Shaped particulates which have been compressed from a composite of a well treatment agent and adsorbent in a matrix may be introduced into horizontal or deviated oil or gas wells. The well treatment agent of the shaped pellets may be used to prevent and/or control the formation of deposits in a production well.

Abstract: A well servicing fluid is formulated by combining ingredients comprising: an aqueous based fluid comprising sulfate ions at a concentration greater than 50 mg/l; a chelating agent; and an acid in an amount sufficient to result in the well servicing fluid having a pH of 4.5 or less. A method of servicing a well is also disclosed.

Abstract: A downhole assembly for delivering chemical treatment to a wellbore at the level of a hydrocarbon-bearing formation is provided. The chemical treatment is in solid phase, and slowly dissolves when exposed to wellbore fluids. A method of treating a wellbore using a solid chemical is also provided.

Abstract: An apparatus has an elongate body defining an interior chamber and a gas passage in communication with the interior chamber. The elongate body further includes a base defining a liquid opening and a cap defining an outlet opening. The liquid opening is adapted to receive a liquid disposed in a wellbore. The gas passage is adapted to receive a gas. An outlet of the gas passage is disposed a first distance from the base and an inner conduit is disposed in the interior chamber. The inner conduit includes a first open end in communication with the liquid opening and a second open end in communication with the interior chamber. The second open end is disposed a second distance from the base.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method that comprises providing a treatment fluid comprising a carrier fluid and temperature-activated polymeric particulates, wherein a compressible gas is trapped in the polymeric particulates; and introducing the treatment fluid into a well bore annulus.

Abstract: A method for routing a fluid within a flowline of a downhole tool is provided. In one embodiment, the method includes moving a piston within a chamber of a downhole tool to push a fluid out of the chamber and into a flowline. The method also includes using a pump in the downhole tool and in fluid communication with the flowline to route the fluid within the downhole tool via the flowline while moving the piston within the chamber. Additional systems, devices, and methods are also disclosed.

Abstract: A method is disclosed for reducing lost circulation in drilling wells, employing composite materials containing an engineering thermoplastic polymer and mineral fibers. Optionally the composites may also include other components such as calcium carbonate and blending agents.

Abstract: This invention presents innovative methods to treat saline streams such as produced water, seawater, and the like. The invention can be used to: (1) de-NORM produced water; or (2) de-NORM and partially de-salt produced water; or (3) de-NORM and partially de-salt and de-ionize produced water; or (4) de-oil, de-NORM, de-salt and de-ionize produced water. The invention can also be used to de-sulfate seawater and the like in conjunction with desalting plants.

Abstract: A method of treating a portion of a well including the steps of: (A) forming a fluid comprising: (i) an aqueous liquid phase; and (ii) a corrosion inhibitor selected from the group consisting of: (a) the leaves of henna, jewelweed, or any combination thereof; (b) an extract of the leaves of henna, jewelweed, or any combination thereof; (c) a plant source of a hydroxynaphthoquinone; (d) a hydroxynaphthoquinone; and (e) any combination an any of the foregoing; and (B) introducing the fluid into the portion of the well.