Abstract: Methods and systems for producing hydrocarbons. An example method includes producing a non-hydrocarbon liquid from a first horizontal wellbore, the first horizontal wellbore extending from a vertical wellbore and through a hydrocarbon producing formation. The method further includes pumping the non-hydrocarbon liquid with a first pump into a second horizontal wellbore, the second horizontal wellbore extending from the vertical wellbore and disposed downhole and underneath the first horizontal wellbore. The method additionally includes pumping a hydrocarbon liquid uphole to a surface with a second pump disposed downhole of the first horizontal wellbore.

Abstract: A method is provided. Sensor data regarding a wellbore is received from at least one of a distributed fiber optic sensing line positioned along the wellbore and a plurality of subsurface and surface sensors. Flow models are generated based on the sensor data to optimize production flow. Flow profiles are generated based on the flow models and the sensor data to adjust at least one gas lift valve.

Abstract: A method of identifying hydrocarbon production information is disclosed. In in a first hydrocarbon management environment, a first audio signal is detected and a characteristic acoustic fingerprint is identified therefrom. The fingerprint is stored in a memory, along with identifying information associated with the first signal. A second audio signal is detected and a characteristic acoustic fingerprint is identified therefrom. The fingerprints are compared, and if the fingerprints match the identifying information of the first audio signal is assigned to the second audio signal. A notification regarding the matching of the characteristic acoustic fingerprints of the first and second audio signals is issued.

Abstract: A method and system for transmitting an electromagnetic (EM) signal in a wellbore to improve an open loop system. The method comprises measuring a parameter indicative of a property of a transmitter using a sensor in the wellbore and generating an input signal for the transmitter based at least in part on the measured parameter to correct distortions exhibited by the output signal of the transmitter. The method comprises also comprises applying the input signal to the transmitter to transmit the EM signal corrected for distortions. The system comprises an antenna, a transmitter, a sensor, and a controller. The controller is configured and operable to generate an input signal for the transmitter based at least in part on the measured parameter to correct distortions exhibited by an output signal of the transmitter; and apply the input signal to the transmitter to transmit the EM signal corrected for the distortions.

Abstract: A chemical tank level system for a wellbore chemical injection tank is provided. The system includes a pressure sensor is located downstream of the chemical injection tank where the fluidic pressure is essentially the same as the fluidic pressure at the base of the chemical tank. The pressure sensor sends a signal indicative of the fluidic pressure to a tank level sensor module. The tank level sensor module receives the signal from the pressure sensor. A processor takes a series of pressure sensor signals over a sample window and calculates an average of the signals over a defined time window.

Abstract: A multi-stage downhole tool movement control system and method of use, such as a multi-stage movement control system to control the speed of a set of plunger tools when operating within a tubing string of a wellbore, such as when rising within a tubing string of a wellbore. The plunger tools operate in designated stages or zones of a tubing string. In one embodiment, the plunger tools are separated by one or more partitioning tools which transfer accumulated fluid between plungers. In one aspect, the multi-stage downhole tool movement control system includes a system controller operating to control a system valve to regulate the plunger tool speed of a selected plunger. The system controller settings are based on a set of system parameters and characteristics of the selected plunger.

Abstract: An annulus safety valve assembly for controlling gas flow in a wellbore annulus that includes a passage, a check valve in the passage, and an actuator that is selectively changed between first and second states. The actuator is bi-stable, and requires no energy to remain in either state. When the actuator is put into one of the states, the check valve configuration is changed from one way flow to two way flow. Reconfiguring the check valve into the two way flow configuration vents lift gas from inside the annulus that is below the check valve.

Abstract: An apparatus performs a method for cleaning a wellbore. The apparatus is a jet sub including an engine, a flow diverter and mixing throat. The engine propels a driving fluid at a first end of the jet sub towards a second end of the jet sub along a longitudinal axis of the jet sub. The flow diverter redirects the driving fluid by a redirection angle that is an obtuse angle. The mixing throat receives a mixed fluid including the driving fluid from the flow diverter and induced fluid drawn into the mixing throat by the driving fluid. The mixed fluid is injected into an annulus of the wellbore at the obtuse angle.

Abstract: The check valve positioned within a production tubing string is configured to open when a differential pressure across the check valve exceeds a specified opening differential pressure. With the check valve closed, a specified volume of gas is flowed from the production tubing string, thereby decreasing the pressure within the production tubing string from a first wellhead pressure to a second, lesser wellhead pressure. Hydrostatic pressure within the production tubing string at the check valve is increased by flowing a specified volume of water into the production tubing string above the check valve to at least partially replace the specified volume of gas. After flowing the water, a specified volume of treatment fluid is injected into the production tubing string at an injection pressure less than the first wellhead pressure and greater than the second wellhead pressure, thereby opening the check valve and flowing the treatment fluid downhole.

Abstract: Apparatuses and methods for extracting gas from a reservoir including a well bore having a large cross sectional area which may be determined by dividing a target flow rate of the reservoir by an actual sustained flow rate and multiplying a result by a flow path area for the actual sustained flow rate. A method of converting a well of a low pressure gas reservoir is further provided.

Abstract: A method for evaluating a gas well productivity with eliminating an influence of liquid loading includes steps of: collecting basic data of a liquid loading gas well; according to a relative density of natural gas, a formation depth, and a casing pressure during a productivity test, determining a pressure generated by a static gas column in an annular space between a casing and a tubing from a well head to a bottomhole of the gas well, and obtaining a bottomhole pressure without liquid loading; according to a pseudo-pressure of a formation pore pressure, pseudo-pressures of the bottomhole pressure respectively under the conditions of liquid loading and no liquid loading, and a production rate under the condition of liquid loading, determining a production rate without liquid loading, and determining an absolute open flow rate with eliminating the influence of liquid loading.

Abstract: A device for generating a flow of crude oil from a plurality of hydrocarbon reservoirs to a surface location, including a set of isolation devices arranged to, at least partially, hydraulically isolate a set of segments of a wellbore traversing each of the plurality of hydrocarbon reservoirs. The device further includes a trap that receives a flow of crude oil from the plurality of hydrocarbon reservoirs and generates a comingled crude oil, and a set of conduits arranged to convey the flow of crude oil from each of the plurality of hydrocarbon reservoirs to the trap, and a blending device that blends the comingled crude oil to produce a blended crude oil. The device further includes a conduit arranged to convey the comingled crude oil from the trap to the blending device, and a conduit arranged to convey the blended crude oil to the surface location.

Abstract: A device for separating an oil phase from an aqueous phase in a remediation well and conveying said separated oil phase to a tank at the surface, wherein said device comprises: a chamber comprising at least two hoses connected to an upper part of the chamber, the hoses being communicated with an interior of the chamber; an oil phase and aqueous phase separating filter, located in the upper part of the chamber and communicated with the interior of the chamber, the filter having a lid on an upper part of the filter; and a hollow float attached to a lower part of the chamber, the float comprising a ballast at a lower end, wherein the ballast comprises a centering body at a lower end.

Abstract: A sand bypass separator is provided for separating particulate matter from a fluid mixture in a production well and directing the separated particulate matter away from a pump intake. The separator includes an outer tube, an inner tube positioned within the outer tube. The outer tube has a plurality of slots to allow the fluid mixture to enter the separator between the outer tube and the inner tube. As the fluid mixture moves downward, the fluid mixture reaches a downward velocity sufficient to allow the particulate matter in the fluid mixture to continue downward as the fluid is drawn into the inner tube through the pump intake. A bypass that extends from above the pump intake to below the pump intake to collect and direct the separated particulate matter separated below the pump intake may also be included.

Abstract: Embodiments described herein comprise a wellbore system having a controller, one or more downhole tools, and a conveyance configured to lower the one or more downhole tools into the wellbore. The one or more control nodes are located in at least one of the downhole tools and wherein the control nodes activate a portion of the downhole tool and data is exchanged between the control node and the controller using a direct sequence spread spectrum signal.

Abstract: An in situ exploitation-separation-backfilling integration apparatus for natural gas hydrates is disclosed, consisting of a cyclonic suction device for coarse fraction, a jet flow device for sand discharge and a spiral cyclone device for fine fraction. The cyclonic suction device for coarse fraction is provided with a vortex trough and a cyclonic auxiliary flow channel; the jet flow device for sand discharge mainly consists of a sand discharge sliding sleeve, a sand discharge jet cylinder and a spring, wherein the sand discharge sliding sleeve can control the spraying out of hydraulic fluid and it is provided with a sand discharge butting head; inside the spiral cyclone device for fine fraction is a tapered structure and its upper portion is provided with a centering bracket.

Abstract: A downhole tool movement control system and method of use, such as a movement control system to control the speed of a plunger tool when operating within a tubing string of a wellbore, such as when rising within a tubing string of a wellbore. In one embodiment, the downhole tool movement control system includes a system controller operating to control a system valve to regulate the plunger tool speed, the system controller settings based on a set of system parameters.

Abstract: Described herein are coated lift plungers, which have improved hardness, durability, and corrosion resistance, as well as methods of making, reworking, and using the same.

Abstract: A phase-separating device for hydrocarbon-contaminated aquifers comprising a support module comprising a central axis, a filter module operatively attached to the lower end of the central axis of the support module, an elastic module operatively attached to the filter module; and a reservoir module.

Abstract: The invention relates to the field of electrical engineering, in particular the design of linear electric motors for submersible installations with a plunger pump, and used for oil extraction. The technical result is to increase the durability of the submersible electric motor and the efficiency of its operation. The stator consists of a cylindrical housing, within which are installed magnetically conductive cups incorporating armature coils and support elements separating the groups of cups, whereby the inner diameter of which is less than the inner diameter of the magnetically conductive cups. On the inner surface of the support elements, grooves are provided, the depth of which is more than half the difference between the inner diameters of the magnetically conductive cups and the support elements. Moreover, the magnetically conductive cups and the support elements are installed in a housing with a radial clearance and are attached therein by fastening elements.

Abstract: A gas lift system may be installed within a well to allow gas lift operations where gas may be injected into the annular area of the well while producing fluids through the interior of the production tubular or upon demand may be reversed so that gas may be injected into the interior of the production tubular while producing fluids to the annular region of the well. In order to allow bidirectional production on demand two types of gas lift mandrels are installed as part of the production tubular. Both types of gas lift mandrels are configured such that gas lift valves are mounted to the exterior of the mandrels. In order to facilitate the desired direction of gas flow through the two types of gas lift mandrels a plug and packer system with or with out one way valves may be utilized to direct and contain the pressurized gas flow within the well.

Abstract: A wellbore pumping system (10) has at least one jet pump (18, 20) disposed in a tubular string (12) inserted into a subsurface wellbore (II). An intake of the jet pump is in fluid communication with a subsurface reservoir. A discharge of the jet pump is in fluid communication with an interior of a tubular string extending to the surface. A fluid bypass (24, 26) fluidly connects the inlet and discharge of the jet pump. The fluid bypass in some embodiments is operable to enable fluid flow when a differential pressure of fluid pumped into the tubular string from the surface exceeds a predetermined pressure. Another aspect includes a pump system having two separately operable jet pumps in tandem in a wellbore tubular string.

Abstract: A gas vent system for use in a wellbore that includes a substantially horizontal portion is provided. The gas vent system includes a gas vent conduit positioned within the wellbore. The gas vent conduit defining a gas vent intake passage situated within the substantially horizontal portion of the wellbore and configured to facilitate a flow of gaseous substances therethrough. A gas vent valve coupled to the gas vent conduit and situated outside the wellbore. The gas vent valve controls the flow of gaseous substances through the gas vent conduit.

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

Abstract: A system can include an upper completion string including an outer mandrel and an inner mandrel positioned coaxially within the outer mandrel. The upper completion string can include a first pressure sensor in communication with a first chamber via a first channel extending through an outer housing of the outer mandrel for detecting a first pressure within the first chamber and transmitting an associated sensor signal. The first chamber can have a boundary that is defined at least in part by (i) an outer surface of the inner mandrel, (ii) an inner surface of the outer mandrel, and (iii) at least two protrusions positioned between the outer surface of the inner mandrel and the inner surface of the outer mandrel. The system can include a computing device in communication with the first pressure sensor for determining a pressure difference between the first pressure and another pressure.

Abstract: A method of controlling a gas vent system to vent gas from a wellbore that includes a substantially horizontal portion. The method includes determining an initial operating mode of the gas vent system; generating one or more control signals established for the determined initial operation mode; and transmitting the one or more control signals to a gas vent valve that commands the closing or opening of the gas vent valve. A controller for use in venting gas from a wellbore is additionally disclosed.

Abstract: A method of enhancing oil or gas production comprises injecting into a well penetrating a subterranean formation a pre-flush fluid to increase water wettability of the well, the subterranean formation, a flowline, or a combination comprising at least one of the foregoing; and injecting into the well a foamer composition.

Abstract: A fracturing method wherein a foamed or energized fluid comprising natural gas is introduced into a subterranean formation to enhance or create fractures and to enhance production of hydrocarbons from a reservoir penetrated by a wellbore.

Abstract: An artificial lifting system for bringing a formation fluid from a horizontal well to the surface. The system includes an outer production tubing that extends into the well, from a head of the well to a toe of a lateral portion of the well; and an extraction support mechanism extending in a bore of the outer production tubing.

Abstract: A permanent magnet submersible motor for electric submersible pump systems and a method of making the rotor of such a motor. The unitary construction of the rotor shaft and the yoke provides improved protection of the damage-prone magnets, while the larger effective shaft diameter also improves shaft bending resistance. Shaped form closures on the yoke promote secure magnet retention, even under highly centrifugal loads, while an exterior cladding tube and a cast resin filler material are used to further secure the magnets around the yoke periphery while also providing hermetic sealing against a working fluid.

Abstract: A method for installing an electrical submersible pump (ESP) in a well containing a production conduit includes securing an ESP to a lower end of a coiled tubing segment containing an electrical power cable. An operator secures a load transfer device with a gripping member to the coiled tubing segment above the ESP. The operator lowers the coiled tubing segment into the well along with the ESP and the load transfer device. The load transfer device contacts an interior side wall of the production conduit with the gripping member and transfers a load on the coiled tubing segment to the production conduit. When powered, the ESP causes well fluid to flow upward from the ESP through the load transfer device up the production conduit.

Abstract: The disclosed device provides a high-accuracy plunger arrival detection system comprising a low-power magnetometer with high sensitivity and which is capable of sampling low or high intensity magnetic fields. The device processes gathered data from sensors, stores at least some processed data in memory, executes a trending algorithm which compares the magnetic field of the plunger to the ambient magnetic field or a predetermined set of initialization values, and generates an output which is relayed to a well controller. An output signal may be via hard wire, RF, wireless or other known means. In addition, the implementation of two sensing devices mounted in series and in spaced relation to each other, can provide for an actual plunger average velocity. An actual plunger average velocity, as opposed to approximate average velocity, can be used to better optimize well control and improve safety of the overall well production system.

Abstract: One illustrative artificial lift method includes deriving compressed natural gas (CNG) from liquefied natural gas (LNG) and employing the CNG to hydraulically drive a downhole pump that forces fluid from the well. An illustrative system embodiment includes an evaporator, a controller, and a downhole pump. The evaporator converts LNG into CNG, which the controller employs to alternately pressurize and depressurize a hydraulic line. The downhole pump includes a plunger that performs a pump stroke in response to the pressurization and a return stroke in response to the depressurization; these pump and return strokes operate to force fluid from a well. Further disclosed herein is the use of a virtual pipeline to supply LNG for such artificial lift systems and methods. It includes: liquefying natural gas to fill a transport trailer at an offsite facility; transporting the trailer to a site of a well; and coupling the trailer to surface equipment.

Abstract: A well screen assembly includes a tubing including a center bore and at least one aperture through the tubing between an outer radial surface of the tubing and an inner radial surface of the tubing; a filtration screen positioned around the tubing; a housing positioned around the tubing and including a fluid chamber in fluid communication with an outlet of the filtration screen; and a flow control device positioned in fluid communication with the outlet of the filtration screen and the at least one aperture to reduce a wall shear stress on at least one of the tubing or the at least one aperture.

Abstract: Methods and apparatus are provided for measuring one or more parameters associated with an artificial lift system for hydrocarbon production and operating the system based on the measured parameters. One embodiment of the invention provides a lubricator for a plunger lift system, which generally includes a housing, a spring disposed in the housing for absorbing an impact by a plunger, and a sensor configured to measure at least one parameter of the spring. One example method of operating a plunger lift system for hydrocarbon production generally includes measuring at least one parameter of a spring disposed in a lubricator of the plunger lift system and operating the plunger lift system based on the measured parameter.

Abstract: A method for monitoring a subsea hydrocarbon production or processing apparatus involves mounting a subsea control module (SCM) on or adjacent the apparatus, mounting a first base unit on or adjacent the apparatus at a distance from the SCM, mounting a plurality of first sensor devices on the apparatus, each of the plurality of first sensor devices being configured to generate a first sensor signal representative of a condition of a component of the apparatus or a property of a fluid in the apparatus, operating each first sensor device to generate a corresponding first sensor signal, wirelessly transmitting each first sensor signal from its corresponding first sensor device to the first base unit, wirelessly receiving the first sensor signals at the first base unit, transmitting the first sensor signals from the first base unit to the SCM, and receiving the first sensor signals at the SCM.

Abstract: A system (10) for drilling a borehole (14) in a subterranean formation (16) containing a fluid (18), comprising: an outer tube (24) defining an outer tube distal end (26) configured for attaching a drill bit (12) thereto and a flow controller receiving section (27) spaced apart therefrom; a flow controller (28) including a flow controller body (30) defining body proximal and distal ends (32 and 34) and securable to the outer tube (24) in the flow controller receiving section (27); and a drilling accessory (36) insertable in the outer tube (24) and through the flow controller (28). The flow controller (28) is movable between open and closed configurations. In the open configuration, the flow controller (28) allows passage of the drilling accessory (36) therethrough. In the closed configuration, the flow controller (28) hinders flow of the fluid therethrough towards the borehole proximal end (20) when the flow controller (28) is located closer to the borehole proximal end (20) than the fluid (18).

Abstract: A technique facilitates regulation of flow through a flow control device to improve a well operation, such as a production operation. The technique utilizes a flow control device which has a valve positioned in a housing for movement between flow positions. The different flow positions allow different levels of flow through a primary flow port. At least one flow regulation element, e.g. a Venturi based flow regulation element, is used in a control line in communication with the valve to establish a differential pressure acting on the valve. The differential pressure is a function of fluid properties and is used to autonomously actuate the flow control device to an improved flow position.

Abstract: A method for estimating equivalent top of fluid level or a theoretical surface annular back pressure in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to compute the equivalent top of fluid level and/or theoretical surface annular back pressure of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of values corresponding to various wellbore intervals. The equivalent top of fluid level and/or theoretical surface annular back pressures may be used in automated managed pressure drilling operations.

Abstract: Apparatus, systems, and methods for continuously circulating drilling fluid through a tubular string are described. The methods include connecting a sub having a central bore and a side bore to the tubular string, connecting a top drive to the tubular string, connecting a manifold to the sub and top drive, wherein the manifold comprises a plurality of electrically controlled valves, and controlling the flow of drilling fluid through the sub and top drive by selectively opening and closing the electrically controlled valves.

Abstract: There is provided a system for producing oil from a well bore extending through a fossil fuel reservoir. The system includes a plurality of perforations defined in the casing proximate the fossil fuel reservoir. A gas flow tube is in communication with the annulus volume of the casing proximate the wellhead. A gas valve is coupled to the gas flow tube, with the gas valve configured to selectively open and close the gas flow tube. A controller, is coupled to the gas valve, with the controller configured to control the opening and closing of the gas valve. The opening and closing of the gas valve maximizes the volumetric rate of oil flow into the annulus volume through the perforations from the reservoir by displacing liquid in the annulus volume with a gas volume between the gas valve and the perforations.

Abstract: A dual barrier side pocket mandrel with gauge includes a gas lift barrier valve mandrel with permanent sensors and at least two pockets for accepting gas lift barrier valves, wherein the pockets are connected via a port. The mandrel also includes a production conduit along a central longitudinal axis. The mandrel is encompassed by a casing on the inside of a well. The permanent sensors can monitor a pressure or a temperature in the casing, production conduit, and port to determine the status of the individual gas lift barrier valves.

Abstract: Methods for converting non-standard frac sand into sand with fracking properties using at least one jet pump.

Abstract: A downhole separator for separating solids from downhole well fluids comprises a cyclonic separation assembly. The assembly comprises a housing with at least one inlet port and an intake member disposed within the housing. The intake member includes a feed tube, a guide member disposed about the feed tube, and a vortex tube coaxially disposed within the feed tube. The assembly also comprises a cyclone body coaxially disposed within the housing and extending axially from the feed tube. In addition, the separator comprises an upper solids collection assembly coupled to the housing and configured to receive the separated solids from the cyclone body. Further, the separator comprises a lower solids collection assembly coupled to the housing and configured to receive the separated solids from the first solids collection assembly.

Abstract: A hydraulic pump smart device for production of oil, recording of pressure and temperature, temporary closing and leveling of pressure in a single and simple operation is provided. The intelligent hydraulic pumping device includes a jet pump assembly coupled with a bottom shut-off valve and is coupled to a gauge carrier, forming an integrated single-block unit. A bottom shut-off valve is incorporated into to the jet pump and is closed by a system of a plunger and two balls. The recovery of the smart device is generated by the opening of a by-pass on injecting a drive fluid in reverse at a low pressure (approximately 100 to 500 psi).

Abstract: A method and system for producing a subsea well includes installing a pump and a gas/liquid separator on a sea floor. The system flows well fluid up the well to the pump, boosting the pressure of the well fluid. The system flows the well fluid from the pump into the gas/liquid separator and separates gas from the well fluid. The stream of liquid flows up a flow line to a remote production facility. The stream of gas is injected back into the well at a selected depth to mix with the well fluid flowing up the well. The injection of gas creates a gas lift system that lightens the hydrostatic pressure of the well fluid in the well.

Abstract: Techniques for reducing a carbon emissions intensity of a fuel includes injecting a carbon dioxide fluid into a first wellbore; producing a hydrocarbon fluid from a second wellbore to a terranean surface; and producing a fuel from the produced hydrocarbon fluid, the fuel including a low-carbon fuel and assigned an emissions credit based on a source of the carbon dioxide fluid.

Abstract: Methods and apparatuses for single tripping a tool for injecting gas into a reservoir to improve production are shown herein.

Abstract: An apparatus, system, and method are provided for deliquefying a produced fluid being produced from a gas well. The apparatus can be a nozzle configured to be disposed in a production tube extending from a subsurface gas reservoir to a surface location and configured to provide a pathway for transmission of the produced fluid from the reservoir to the surface location. The nozzle generally can define a first end for receiving the produced fluid from the reservoir, a second end distal to the first end, and an inner surface extending between the ends. The inner surface can define an inwardly tapered inlet portion at the first end, an outwardly tapered outlet portion proximate the second end, and a venturi neck portion between the inlet and outlet portions. The nozzle can be configured to reduce the pressure of the produced fluid and thereby deliquefy the produced fluid passing therethrough.

Abstract: A distributed artificial lift system is configured for use in a wellbore that includes a vertical section and at least one lateral section connected to the vertical section. The distributed artificial lift system includes a first remote assembly positioned within the first lateral section. The first remote assembly includes an equipment deployment vehicle and cargo selected from the group consisting of electric remote pumping units, tubing, tubing connectors, tubing adaptors, sensor packages, gas separators, perforating tools, injection pumps and other downhole components. The first remote assembly is optionally self-propelled and remotely-controlled.