Abstract: A borehole pump system includes an immersion pump (20) and a riser (15) accommodated in the borehole (10). A water treatment system for cleaning pumped water is disposed in the riser.

Abstract: A system usable with a well includes a waveform generator for enhancing fluid recovery from a reservoir by controlling a production pump or an injection pump downhole in the well with waveform signals to create a pressure wave which propagates into the reservoir and enhances the recovery of the fluid.

Abstract: A method of optimizing production of wells using choke control includes generating, for each well, an intermediate solution to optimize the production of each well. The generating includes using an offline model that includes a mixed-integer nonlinear program solver and includes using production curves based on a choke state and a given wellhead pressure. The method further includes calculating, using a network model and the intermediate solution of each well, a current online wellhead pressure for each well. The method further includes setting the intermediate solution as a final solution based on determining that a difference between the current online wellhead pressure of each well and a prior online wellhead pressure of each well is less than a tolerance amount. The method further includes adjusting, using the final solution of each well, at least one operating parameter of the wells.

Abstract: Present embodiments are directed to a control system including a controller configured to regulate a drilling fluid flow through a pipe element during installation of the pipe element into a wellbore or removal of the pipe element from the wellbore, wherein the controller is configured to regulate the drilling fluid flow based on feedback from one or more sensors of the control system.

Abstract: Primary and secondary pump assemblies are mounted to and supported by a supporting device in a well. The supporting device has a valve that has a first position allowing flow from the primary pump assembly while the secondary pump assembly is in a storage mode, and a second position allowing flow from the secondary pump assembly. A barrier in the intake of the secondary pump assembly blocks entry of well fluid into the secondary pump assembly while the valve is in the first position. The secondary pump is filled with a buffer fluid. A pressure compensator mounted to the secondary pump assembly has a movable element that moves in response to a difference between well fluid pressure on an exterior of the secondary pump assembly and the pressure of the buffer fluid contained in the secondary pump to reduce a pressure differential.

Abstract: A method, apparatus and computer-readable medium for stimulating a formation is disclosed. A stimulation operation is performed at a selected stimulation zone of the formation using a first value of stimulation parameter. A temperature measurement profile is obtained at the formation during the stimulation operation, wherein the obtained temperature measurement profile is indicative of a parameter related to the stimulation operation. The downhole parameter is determined using the obtained temperature measurements, and stimulation parameter is altered to a second value in real-time based on the determined parameter.

Abstract: Various systems and methods for implementing and using a variable stiffness downhole tool housing include cylindrical segments positioned along a common axis, with a pair of segments each coupled to a bulkhead and positioned at either axial end of the tool housing. The housing also includes a flexible cylindrical sleeve, positioned along the common axis between two of the plurality of cylindrical segments, that includes a first and second region with an outer diameter no larger than a common segment inner diameter and a third region located between the first and second regions and with an outer diameter no larger than a common segment outer diameter (the first and second regions each at least partially inserted into an end of one segment). A stiffness controller controls the stiffness of the tool housing by controlling at least part of an axial force exerted between the two segments.

Abstract: The invention pertains to methods and apparatus for monitoring loads on an arched tubing guide of a coiled tubing injector caused by tension on coiled tubing. The load is sensed by a load sensor, for example, a load cell placed in a strut that supports the arched tubing guide, or in a load pin or load cell placed within the structure arched tubing guide or the connection of the arched tubing guide to a frame for the coiled tubing injector, at a location where the load is representative of the load placed on an arched tubing guide by tension in the coiled tubing. The load sensor generates a feedback signal. The load is monitored, either by an operator or a controller, and torque applied to a reel around which the tubing is wound is adjusted to avoid, or in response to, excessive loads on the arched tubing guide.

Abstract: A power supply for a wired pipe system is provided. The power supply includes energy storage capabilities, and provides for operation in high temperature environments.

Abstract: A system, including an ultrasonic flow meter with a conduit including a conduit wall and configured to flow a fluid, an housing disposed about the conduit to define a fluid chamber about the conduit, wherein the conduit facilitates fluid flow into the fluid chamber and through the ultrasonic flow meter and a first ultrasonic transducer disposed in the fluid chamber.

Abstract: In one example of a rotationally independent wellbore ranging system, a housing attached to a rotary component is positioned in a first wellbore and remains substantially stationary relative to the first wellbore when the rotary component rotates in the first wellbore. Multiple sensors affixed to the housing are operable to receive multiple ranging signals from a second wellbore while the rotary component rotates in the first wellbore, and provide the multiple ranging signals to a processor to determine a position of the first wellbore relative to the second wellbore.

Abstract: Wellbore assembly for injecting fluid into a subsurface formation having multiple intervals comprising a plurality of packers having bypass channels at desired locations between the respective intervals. The assembly allows fluid to be injected down a tubing string, back up an annular region, and through the series of packers to impart incremental pressure drops along the intervals. The assembly enhances pressure support by allowing the operator to optimize wellbore injection along intervals having different formation characteristics.

Abstract: A completion tool for gravel packing screens incorporates an added position to allow redirection of flow to a signal transmission tool at the needed flow rates to optimize signal to noise ratios by creation of a discrete flow path that channels the desired flow directly to the device and using the production tubing and upper annulus as the balance of the flow circuit. The Smart Collet® has a landing location for this position which is preferably between the circulation and reverse positions of the crossover tool. The wash pipe assembly can have a shifting tool that closes the sleeve over the gravel exit ports for the information transmittal such ports can thereafter remain closed because the gravel packing is complete but for the reversing out of excess gravel which happens above the gravel exit ports.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to advance a sampling and guard probe (100) with a surrounding sealing pad (108) against a borehole wall, to adjust the size of the area associated with a fluid flow inlet of the probe, where the size of the inlet area (104) is selectably and incrementally variable, and to draw fluid into the fluid flow inlet by activating at least one pump (344) coupled to at least one fluid passage (128) in the probe. Additional apparatus, systems, and methods are disclosed.

Abstract: The present disclosure relates to determining hydrogen indexes of downhole fluids using fluid composition data. In certain embodiments, the type of the fluid, such as gas, water, or oil, may be determined downhole and used to select a method for determining the hydrogen index of the fluid. The selected method may then be employed while the tool is downhole to calculate the hydrogen index of the fluid.

Abstract: A system usable with a well includes a waveform generator for enhancing fluid recovery from a reservoir by controlling a production pump or an injection pump downhole in the well with waveform signals to create a pressure wave which propagates into the reservoir and enhances the recovery of the fluid.

Abstract: Well conduit system and methods using a first outer conduit wall and at least one second inner conduit wall positioned through a wellhead to define an annulus with radial loading surfaces extending across the annulus and radially between at least two of the conduit walls to form passageways through subterranean strata concentrically, wherein an inner pipe body of greater outer diameter is inserted into an outer pipe body of lesser inner diameter by elastically expanding the circumference of the outer pipe body and elastically compressing the circumference of the inner pipe body, using a hoop force exerted therebetween. Releasing the hoop force after insertion will release the elastic expansion and compression of the pipe bodies to abut the radial loading surfaces within the annulus for sharing elastic hoop stress resistance and thereby forming a greater effective wall thickness, capable of containing higher pressures than the conduit walls could otherwise bear.

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 includes pumping fluid from outside of a downhole tool through a flowline of the downhole tool with a pump and taking first measurements, using at least one sensor, within the flowline during a first stage of pumping the fluid. The method further includes estimating a saturation pressure of the fluid, via a processor, based on the first measurements and a saturation pressure model generated based on second measurements taken using the at least one sensor during a second stage of pumping the fluid, and operating the pump to maintain a fluid pressure in the flowline greater than the estimated saturation pressure.

Abstract: An apparatus for controlling fluid in-flow into a wellbore tubular includes a translating flow control element having one or more fluid conveying conduits; and a reactive element that actuates the flow control element. The reactive element may be responsive to a change in composition of the in-flowing fluid. The reactive element may change volume or shape when exposed to or not exposed to a selected fluid. The selected fluid may be oil, water, or some other fluid (e.g., liquid, gas, mixture, etc.). The reactive element may slide the flow control element such that a conduit formed on the flow control element changes length, which then changes a pressure differential across the flow control element.

Abstract: A system for pump down operations includes a diversion valve unit that is adjustable between a pumping position and a diversion position and a controller coupled to the diversion valve unit. The system further includes a fluid reservoir, a downhole fluid path between the fluid reservoir and a tool downhole, a driving unit in the downhole fluid path for advancing the tool, and a diversion fluid path between a portion of the downhole fluid path downstream of the driving unit and the fluid reservoir or another fluid receptacle. The diversion valve is in the diversion fluid path and the controller automates the diversion valve position for the diversion valve unit based on a monitored wireline speed or a monitored wireline tension for a wireline unit.

Abstract: The invention relates to an apparatus and a method for opening and closing an automatic valve installed in the discharge line of an oil well, characterized by the installation and setup of the apparatus which controls an automatic valve, which is installed in the discharge line of the casing pipes of an oil well. In said oil well a progressive cavity pump system (PCP) has been installed, which pumps the hydrocarbon to the storage tank through the production pipe, said system maintaining the level of hydrocarbon inside the well for improved production. The apparatus to be installed in the oil well consists of three pressure transmitters, which are placed in the discharge lines of the production pipes, casing pipes and in the discharge line going into the storage tank near the well. In addition, in the storage tank, a radar-type level transmitter is installed to keep monitoring the production from the oil well.

Abstract: A method, software, and apparatus for controlling a pump configured to pump liquid out of a well. Such control may involve determining whether a production rate of gas from the well is increasing, decreasing, or steady, and whether to switch the pump between an OFF state and an ON state. Whether the pump is switched may depend upon whether the production rate of the gas is determined to be increasing, decreasing, or steady.

Abstract: A tubular closure assembly responsive to speed or velocity of an object. The tubular closure assembly includes at least one sensor in operable communication with an interior of a tubular. The at least one sensor sensing an object passing a first point and then a second point within the tubular. A processor receiving an output from the at least one sensor and calculating speed of the object from the first point to the second point. A control panel receiving information from the processor and a closure system movable between an open condition and a closed condition. Activatable to the closed condition by the control panel in response to the object moving from the first point to the second point at speed faster than a preset value or at a velocity outside a preset range. Also included is a method of closing a tubular of a borehole.

Abstract: A downhole electrical power grid electrically connects a string of downhole tools including at least a first power generating tool and a second power consuming tool. The power generating tool includes a power generator, an electric load, and a power management controller. The power management controller is configured to automatically electrically connect and disconnect the tool from the power grid. The power generating tool may include a rotary steerable tool having a power generator, an electric actuator, and the aforementioned power management controller.

Abstract: A downhole pump assembly for pumping production fluid to a surface of a well. The downhole pump assembly includes a fluid pump that is operable to pump the production fluid to the surface. An optical computing device having at least one integrated computational element and at least one detector. The at least one integrated computational element is configured to optically interact with the production fluid proximate the fluid pump and is configured to generate optically interacted light. The at least one detector is arranged to receive the optically interacted light and to generate an output signal corresponding to a characteristic of the production fluid.

Abstract: The present invention relates to a method for controlling a drilling or cutting operation performed by a wireline tool downhole, comprising the steps of commencing a drilling or cutting operation in a downhole object, such as a casing or valve; detecting vibration produced during the drilling or cutting operation in the downhole object using a vibration sensor adapted to transmit detected vibrations; processing a vibration signal from the vibration sensor to produce a real-time frequency spectrum; comparing the frequency spectrum to a reference frequency spectrum; and controlling the operation based upon the comparison of the frequency spectrum and the frequency spectrum specification. Furthermore, the present invention relates to a wireline tool for performing a drilling or cutting operation downhole and carrying out the method according to the invention.

Abstract: Back pressure control devices used to control fluid pressure in a wellbore require various utilities for operation, such as an air supply. Apparatus disclosed herein provide for the continued operation of one or more back pressure control devices when supply of utilities for operation of the back pressure control devices are intentionally or unintentionally interrupted.

Abstract: A self-contained cut-off device for the use in oil and gas extraction comprises a body, a stop valve, a potential energy accumulator, and a hold-release arrangement. The arrangement, fixed in the body, is equipped with clamping elements. The valve comprises a drum-shaped valve head and a seat. The head outer surface has a conical groove for the clamping elements. On the inside, the head has a through passage for a flow with a conical portion expanding from the inlet to the outlet, and with a cylindrical portion at the outlet. The head comprises a replaceable nipple in the inlet of the passage. The seat comprises circulation passages in its annular part and has a boss made with a cylindrical surface and a spherical surface adapted to mate the cylindrical and conical portions of the passage, respectively. A sealed cavity for a lubricant is formed between the body and outer surface.

Abstract: A method for modeling flow properties over a series of time increments of a reservoir in an earth formation having a plurality of fractures is disclosed. The method includes: building a three-dimensional stress field representing stresses in the reservoir; building a three-dimensional discrete fracture network (NFM) having fracture flow properties using information obtained from a tool or changes to the stress field; running a flow simulation of the reservoir for a time increment using the NFM to model the flow properties of the reservoir for that time increment; computing a latest change in the three-dimensional stress field from the flow simulation; and incrementing the time increment and iterating the building the NFM using the latest change in the stress field, the running of the flow simulation using the latest NFM, and the computing a latest change in the stress field from the latest running of the flow simulation.

Abstract: Tunable down-hole stimulation systems feature closed-loop control of pumps and tunable down-hole stimulators. Stimulators generate and hydraulically transmit broad vibration spectra tuned for resonance excitation and fracturing of geologic materials adjacent to the wellbore. Feedback data for controlling stimulation includes backscatter vibration originating in stimulated geologic material and detected at the stimulator(s). For initial fracturing with relatively large particle sizes, the power spectral density (PSD) of each stimulator output is down-shifted toward the lower resonant frequencies of large particles. As fracturing proceeds to smaller (proppant-sized) fragments having higher resonant frequencies, backscatter vibration guides progressive up-shifting of stimulator PSD to higher vibration frequencies. Stimulator power requirements are minimized by concentrating vibration energy efficiently in frequency bands to which geologic materials are most sensitive at every stage of stimulation.

Abstract: A subterranean tool that is self contained for actuation can be run into a desired location on an automatic set mode controlled by a timer. If a problem develops in getting the tool to the desired location in time a magnetic field created by permanent or electro-magnets can be brought to bear on the tool to stop the timer before the tool actuates. Once the tool is subsequently positioned at the desired location another magnetic field can be brought to bear near the tool to set it. Alternatively, the tool can be run to the desired location without activation with the timer and then the magnetic field can be brought to the tool to set it. The magnetic field can be lowered to the tool with wireline or can be dropped or pumped past the tool to actuate the tool. Optionally the field can be generated from within an object that ultimately lands on a seat to provide a backup way to set the tool using tubing pressure.

Abstract: A hydrostatically set packer is held against setting by a locking member that is made of controlled electrolytic material (CEM). After introduction into a wellbore and exposure to thermal or well fluid inputs the lock made of CEM dissolves or is otherwise weakened to the point where relative movement can occur for the setting of the packer with available hydrostatic pressure. The locking member can also be a shape memory alloy at least in part whose shape change allows the tool to set.

Abstract: A method and apparatus to regulate the down-hole hydrostatic pressure in a wellbore are provided which depend on regulating the resistance to the flow of wellbore returns produced by the wellbore. The resistance may be provided by the internal gas pressure in a gas/liquid separator receiving the flow of wellbore returns, where the internal gas pressure is regulated by an adjustable back pressure valve and a gas source. Alternatively or in addition, the resistance may be provided by a pump receiving the flow of wellbore returns, where the resistance of the pump is regulated by adjusting the speed of the pump.

Abstract: The present invention relates to an annular barrier system (100) connected with a well head (40) via a well tubular structure (3), comprising a first annular barrier (1) and a second annular barrier (21) to be expanded in an annulus (2) between the well tubular structure and an inside wall (4) of a casing (20) or a borehole (5) downhole for providing zone isolation between a first zone (8) and a second zone (9), each annular barrier comprising a tubular part (6) extending in a longitudinal direction for mounting as part of the well tubular structure, an expandable sleeve (7) surrounding the tubular part and defining a space (13), an opening (11) for letting fluid into the space to expand the sleeve, and a first connection part (15) and a second connection part (16) connecting the expandable sleeve with the tubular part, and wherein the first connection part is arranged nearest to the well head, the system further comprising a flow line (17) fluidly connecting the well head with the opening for supplying fluid

Abstract: A plunger lift control system for improving the output efficiency of an oil or gas well by a real-time reporting arrangement, the system comprising: a tubing string having an upper end and a lower end, the tubing string arranged within a well casing for receiving a plunger traveling therethrough, a plunger having a sound generating function therewith, so as to transmit a real-time lower-end location signal from the plunger to a signal sensor and processor arranged in communication with a system controller arranged at the upper end of the tubing.

Abstract: A method (50) and an assembly (10) for milling an obstruction disposed within a wellbore (W) includes a milling module (12) having a motor (22) rotating a milling bit (14), a first electronics cartridge (26) for controlling the motor based upon a motor torque value, a tractor module (16, 18) for engaging with the wellbore and providing a push force against the wellbore to urge the milling assembly in a direction of the milling bit, and a second electronics cartridge (28) for controlling a push force value of tractor module. The method involves rotating the milling bit (54) and engaging the tractor module with the wellbore (56), and adjusting, iteratively, the operation (58) based on a calculated torque value and a calculated push force value to maintain the calculated values at around a target torque value and below a push force limit value (66, 70).

Abstract: A flow control system for use in a subterranean well can include a flow chamber through which a fluid composition flows, and a plug which is released in response to an increase in a ratio of undesired fluid to desired fluid in the fluid composition. Another flow control system can include a flow chamber through which a fluid composition flows, a plug, and a structure which supports the plug, but which releases the plug in response to degrading of the structure by the fluid composition. Yet another flow control system can include a flow chamber through which a fluid composition flows, and a plug which is released in response to an increase in a velocity of the fluid composition in the flow chamber.

Abstract: A control system for controlling the operation of a Downhole Steam Generator (DHSG) system includes a cascade control strategy for control of individual final control elements in communication with a local well master controller. The final control elements may control fuel, oxidant, feedwater, and/or carbon dioxide flow to the downhole steam generator. The local well master controller may monitor and adjust the flows to the DHSG to control the operating performance of the DHSG.

Abstract: A self-contained cut-off device for the use in oil and gas extraction comprises a body, a stop valve, a potential energy accumulator, and a hold-release arrangement. The arrangement, fixed in the body, is equipped with clamping elements. The valve comprises a drum-shaped valve head and a seat. The head outer surface has a conical groove for the clamping elements, On the inside, the head has a through passage for a flow with a conical portion expanding from the inlet to the outlet, and with a cylindrical portion at the outlet. The head comprises a replaceable nipple in the inlet of the passage. The seat comprises circulation passages in its annular part and has a boss made with a cylindrical surface and a spherical surface adapted to mate the cylindrical and conical portions of the passage, respectively. A sealed cavity for a lubricant is formed between the body and outer surface.

Abstract: An underreamer for increasing a diameter of a wellbore. The underreamer may include a body having an axial bore extending at least partially therethrough. An electromagnetic activation system may be disposed at least partially within the bore of the body. A valve may be disposed within the bore of the body and coupled to the electromagnetic activation system. The valve may include a mobile element and a static element. The mobile element may be coupled to the electromagnetic activation system and move from a first position where the mobile element obstructs fluid flow through the valve to a second position where the mobile element permits fluid flow through the valve. A cutter block may be movably coupled to the body and move radially-outward as the mobile element moves from the first position to the second position.

Abstract: In some aspects, an injection treatment of a subterranean region is controlled based on a target net treating pressure. A measure of fluid pressure acting on a subterranean region during an injection treatment is received. The measure of fluid pressure is compared against a target net treating pressure for fluid acting on the subterranean region during the injection treatment. The target net treating pressure is associated with a target fracture growth orientation. The injection treatment is modified based on a result of the comparison.

Abstract: In one aspect, a production system is disclosed that in one embodiment may include a production tubing placed inside the wellbore, an ESP in the wellbore for flowing fluid from the wellbore into the production tubing, a sensor string including distributed sensors along the sensor string that provides temperature measurements along the production tubing uphole of the ESP, and a controller that determines from the temperature measurements a change in temperature that exceeds a threshold and determines therefrom level of a liquid in the wellbore.

Abstract: A well tool comprising a housing comprising ports and defining a flow passage, an actuator, a dual magnetic sensor actuation assembly (DMSAA) in signal communication with the actuator and comprising a first magnetic sensor up-hole relative to a second magnetic sensor, and an electronic circuit comprising a counter, and wherein, the DMSAA detects a magnetic signal and determines the direction of movement of the magnetic device emitting the magnetic signal, and a sleeve slidable within the housing and transitional from a first position in which the sleeve prevents fluid communication via the ports to a second position in which the sleeve allows fluid communication via the ports, wherein, the sleeve transitions from the first to the second position upon recognition of a predetermined quantity of magnetic signals traveling in a particular direction.

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: In one aspect, a wellbore system is disclosed that in one embodiment may include a coil in the wellbore, a magnetic element conveyed from a surface location configured to oscillate or rotate in an opening in the coil to generate electrical energy, and a device in the wellbore that utilizes the generated electrical energy.

Abstract: A hydraulic regulating mechanism for disposal in a well. The mechanism includes a degradable metal based element and a swellable component for hydraulic regulation. The mechanism is configured for ease of setting and removal by allowing degrading of the metal based element upon exposure of certain downhole conditions to trigger shrinking of the swellable component. Further, the swellable component may be initially set by exposure to downhole conditions as well. Ultimately, a mechanism is provided which may effectively regulate high pressure applications downhole and yet, as a practical matter, be removed via a displacement or drill out that may take less than 15 to 30 minutes to achieve.

Abstract: An arrangement for extraction of hydrocarbons includes a flow conduit that leads from a subsurface region to an above-surface region. A normally-closed shut-in valve is located in the subsurface region of the flow conduit. A hydraulic system is arranged to cause the shut-in valve to open when the hydraulic system is pressurised. A release valve releases pressure in the hydraulic system. A wireless interface having a unique identifier is adapted to open the release valve on receipt of a wireless communication from a remote device. A plurality of remote devices each include a wireless transmitter that is compatible with the wireless interface and able to transmit control instructions to the wireless interface. At least one control instruction in any sequence of control instructions is issued by the remote device including the unique identifier. The wireless interface is adapted to ignore control instructions containing an identifier differing from the unique identifier.

Abstract: An interlock device for connection within a load path of a tubular support device to lock the tubular support device in a closed position in response to detecting a load suspended from the tubular support device. The interlock device includes a first member moveably connected to a second member and a biasing mechanism operationally connected to the first member and the second member providing a load setting resisting movement of the first member and the second member relative to one another. The first and the second member may be rotationally locked with one another to transmit rotation across the interlock device to the elevator.

Abstract: An apparatus for fluid treatment of a borehole includes: a tubular body having a long axis and an upper end, a first port extending through the wall of the tubular body, a second port extending through the wall of the tubular body, the second port having a fluid inflow control mechanism positioned to control the flow of fluid into the tubular body through the port, the first port being configurable from an open position to a closed position; and a controller to actuate the first port into the closed position, a set time after the first port is placed into the open position.