Abstract: It is provided a dedicated winding tester for composite wire rod-type specimens for effectively measuring the minimum winding radius of the wire rod-type specimens being made with carbon fiber or glass fiber reinforced composites in various diameters or textures via automatically gripping specimens, tightly winding, and sequentially proceeding sustained load in time, thereby supplying test data and design consideration in actual use and transport of the wire rod-type specimens being made of carbon fiber or glass fiber reinforced composites that comprises a shield, a specimen receiver and a winding device being arranged within said shield, as well as a programmable controller being arranged outside the shield.

Abstract: A carrier assembly having at least one sealing cup, a fluid bypass and adjustable wash nozzles, as well as a spear assembly having a central through bore, are attached to the distal end of a length of continuous tubing and inserted in to the flow bore of a pipeline. Fluid is pumped through the annular space between the carrier assembly and the pipeline, providing motive force for advancing the carrier assembly within the pipeline. Fluid can bypass the carrier assembly, enter the central bore of the spear assembly, and return to the surface through the central bore of the continuous tubing. A stuck pig or other obstruction is speared, and thereafter retrieved from the pipeline on the continuous tubing.

Abstract: An assembly for monitoring a fluid operation including a plug member operatively arranged to impede fluid flow past the plug when the plug member is engaged with a seat. A conveyor is coupled to the plug and operatively arranged for positioning the plug at a desired location. A signal conductor is disposed with the conveyor. At least one sensor is coupled with the signal conductor for monitoring one or more parameters related to the fluid operation. A method of monitoring a fluid operation is also included.

Abstract: In some aspects, techniques and systems for operating a subterranean region model are described. Sub-matrices and entries outside the sub-matrices in a first band matrix are identified. The first band matrix includes flow variable coefficients based on governing flow equations of a model representing well system fluid flow in a subterranean region. For each of the sub-matrices, a reduced-size matrix is generated based on the sub-matrix and a subset of the entries that are associated with the sub-matrix. A second band matrix is generated based on the reduced-size matrices. The model is operated based on the second band matrix.

Abstract: A monitoring tool, including an obstructor portion operatively arranged to impede fluid flow past the monitoring tool when the obstructor is engaged with a corresponding seat member. A disintegrable portion is included formed from a material operatively arranged to disintegrate upon exposure to a selected fluid. A gauge is coupled with the obstructor portion and the disintegrable portion. The gauge is operatively arranged to monitor one or more parameters and released from the obstructor portion when the disintegrable portion is disintegrated by the selected fluid. A method of monitoring one or more parameters is also included.

Abstract: In some aspects, techniques and systems for operating a subterranean region model are described. A block matrix is identified. The block matrix includes a banded portion and an augmented portion. The banded portion includes flow variable coefficients based on governing flow equations of a model representing well system fluid flow in a subterranean region. In a row of the block matrix, decomposition of a pivot element in the row is performed. Elements along the row are modified based on an inverse of the decomposition of the pivot element. A flow variable of the model is solved based on the block matrix that contains the modified elements.

Abstract: A system, method and device may be used to monitor fluid levels in a drill pipe in borehole. The system includes an electromagnetic (EM) generator to generate a traveling wave of electromagnetic energy to propagate along a linear path through the drill pipe towards a surface of the fluid, a detector to detect a portion of the electromagnetic wave reflected from the surface of the fluid and propagated through the drill pipe towards the detector, a processor to analyze detected signals to determine a level of the surface of the fluid. In an embodiment, the system includes a pump controller to control the operation of a pump located in the wellbore or at the mudline based on the fluid surface level.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to activate a thermal source in a borehole to heat a portion of a geological formation proximate to the borehole, to move the thermal source or thermal receivers within the borehole (to reduce the distance between the location of heating by the thermal source and one or more of the thermal receivers), to receive signals from one or more of the thermal receivers, responsive to activation of the thermal source, wherein the moving serves to reduce a time between heating the location and the receiving, and processing the signals, distance information related to the moving, and time of the receiving to determine a thermal property of the geological formation. Additional apparatus, systems, and methods are described.

Abstract: Systems and methods of production control are contemplated in which one or more multiphase flow meters are operationally coupled to a production conduit to provide flow and compositional information for the fluid in the production conduit. Data from the multiphase flow meter are then provided to a control system that uses the data to control operation of one or more choke valves of one or more well heads that are fluidly coupled to the production conduit.

Abstract: A method for the controlled delivery of a fracturing fluid to a well bore comprises formulating an aqueous base fluid such that it meets or exhibits desired physical and chemical characteristics for an optimal fracturing fluid. The formulation of the aqueous base fluid max involve commingling one or more sources of waste water with a source of fresh water followed by controlled injection of one or more additives. This process is substantially completed prior to delivering the aqueous base fluid to the well site. This allows the delivery of an optimal volume of the aqueous base fluid with homogeneously blended additives to the well bore.

Abstract: Method and apparatus for estimating a kerogen (organic) porosity of an earth formation. The method may include using at least one processor to estimate a kerogen porosity using NMR signals indicative to an inorganic porosity and NMR signals indicative of a total porosity for a volume of interest in an earth formation. The apparatus may include an NMR tool configured to acquire NMR signals indicative to an inorganic porosity and NMR signals indicative of a total porosity for a volume of interest in an earth formation.

Abstract: A formation monitoring system includes a casing. An array of electromagnetic field sensors is positioned in the annular space and configured to communicate with the surface via a fiberoptic cable. A computer coupled to the fiberoptic cable receives measurements from the array and responsively derives the location of any fluid fronts in the vicinity such as an approaching flood front to enable corrective action before breakthrough. A formation monitoring method includes: injecting a first fluid into a reservoir formation; producing a second fluid from the reservoir formation via a casing in a borehole; collecting electromagnetic field measurements with an array of fiberoptic sensors in an annular space, the array communicating measurements to a surface interface via one or more fiberoptic cables; and operating on the measurements to locate a front between the first and second fluids.

Abstract: A method of optimizing underground drilling in which the Specific Energy, such as the Mechanical Specific Energy, is determined at a plurality of weight on bits and drill bit rotary speeds. The drilling operation is optimized by drilling at the operating conditions, including weight on bit and drill bit rotary speed, at which the standard deviation in Mechanical Specific Energy is a minimum. The drilling operation is monitored by determining the Mechanical Specific Energy and changing the operating parameters if the standard deviation in the Mechanical Specific Energy exceeds a predetermined value.

Abstract: The invention relates to a handling device for drill pipes (18) and to a so-called top drive (16) comprising said handling device, a so-called pipe handler, and having means for detecting a position of an elevator bail (30) comprised by the handling device/pipe handler and for transmitting the associated position information, wherein the position information is transmitted from the pipe handler to, e.g., the top drive (16) and is converted into an electrical signal for detecting and avoiding potentially critical situations as a result of a position/deflection of the elevator bail (30).

Abstract: Apparatuses and methods for retrieving a tool or bottom hole assembly. The apparatus may include a latching device that couples to a tool or bottom hole assembly to be retrieved and at least one seal extending radially from the apparatus to engage an inner diameter of a tubular, such as a casing string. A pump inlet is disposed in or through an outer surface of the apparatus uphole of the at least one seal. A pump outlet is disposed in or through an outer surface of the apparatus downhole of the at least one seal. The apparatus may also include a pump for pumping a drilling fluid from the pump inlet to the pump outlet in order to generate a differential pressure across the at least one seal and provide a hydraulic force to effect retrieval of the tool or bottom hole assembly.

Abstract: A differential pressure indicator (DPI) for use with a downhole isolation valve includes a tubular mandrel for assembly as part of a casing string and for receiving a tubular string. The mandrel has a stop shoulder and a piston shoulder. The DPI further includes a tubular housing for assembly as part of the casing string and for receiving the tubular string. The housing is movable relative to the mandrel between an extended position and a retracted position and has a stop shoulder and a piston shoulder. The DPI further includes a hydraulic chamber formed between the piston shoulders and a coupling in communication with the hydraulic chamber and for connection to a sensing line. The housing is movable relative to the mandrel and to the extended position in response to tension exerted on the DPI.

Abstract: An exemplary automated system and method are provided for monitoring and controlling the transfer of water to frac water tanks during hydraulic fracturing. In one embodiment, the automated system includes a first manifold, a plurality of controllable valves, a plurality of level indicators, a pump, controller(s), storage device, and display. In one implementation, the controller is configured to control the opening/closing of the plurality of controllable valves based, at least in part, on the water levels of the frac water tanks. The controller(s) may include one or more control modes. In other implementations, the system may include a second manifold (or additional manifolds) and the capability to blend water from two or more sources, such as from an impaired water source, using either a single or multiple-manifold configuration. In other implementations, an assembly is provided, such as a skid or trailer mounted assembly, for use in a mobile automated system.

Abstract: A method of monitoring fluid flow in a borehole includes measuring acoustics at a plurality of locations along a downhole assembly in a borehole and calculating a fluid flow rate at the plurality of locations along the downhole assembly based on measuring the acoustics at the plurality of locations.

Abstract: A matrix acidizing monitoring system wherein a sensor array is operably associated with a matrix acidizing bottom hole assembly and contains first and second sets of sensors that detect a matrix acidizing operational parameter at different times at one or more particular locations along the wellbore. This allows the effectiveness of the acidizing to be modeled.

Abstract: A method of predictive modeling of a treatment fluid comprises: determining the value of properties of a base fluid and insoluble particulates; providing a proposed suspending agent; performing a first calculation of the suspendability of the proposed suspending agent as determined by a yield gravity function equation; evaluating if the result from the first calculation indicates a stable treatment fluid comprising the base fluid, the insoluble particulates, and the proposed suspending agent, or if the result does not indicate a stable treatment fluid, then: modifying the value of at least one of the properties of the proposed suspending agent, base fluid, and/or insoluble particulate; and performing a second calculation, wherein the same or different property values are continued to be modified and the calculation is continued to be performed until the result indicates a stable treatment fluid; and introducing the stable treatment fluid into a wellbore.

Abstract: This disclosure provides embodiments of computer implemented methods, computing apparatuses, and other methods for determining reserves of a reservoir. For example, an embodiment of the computer implemented method includes receiving field data for a field that comprises a reservoir, wherein the field data includes pressure data and cumulative production data. The embodiment further includes generating normalized pressure values for a plurality of timestamps using time, the pressure data, and the cumulative production data. The embodiment further includes generating a normalized pressure graph, wherein the normalized pressure graph includes a normalized pressure curve of the generated normalized pressure values.

Abstract: A system and method for reducing borehole effects in a borehole within a subterranean formation is disclosed. The apparatus includes a fluid excluder, which includes a sleeve body and a sleeve opening defined by the sleeve body. The sleeve may be sized to fit around an induction tool. The sleeve body may include a fluid passageway therethrough, which may divert drilling fluids when the apparatus is deployed downhole. The apparatus may further include an electrode disposed within the fluid passageway for reducing the electrical current in the drilling fluid and thereby improve the readings obtained by logging devices.

Abstract: A system to grip a tubular member and sense wear for a pipe handling apparatus including the pipe handling apparatus having a bore formed therein with an axis defined therethrough, a pipe guide disposed adjacent to an opening of the bore of the pipe handling apparatus, and a wear sensor coupled to the pipe guide.

Abstract: A method for fracturing a formation in a reservoir uses a fracturing fluid mixture comprising natural gas and a base fluid. The method comprises: determining certain reservoir conditions of the reservoir comprising the formation; selecting at least one desired behavior of the fracturing fluid mixture during a fracturing operation in the formation under the determined reservoir conditions; determining properties of the fracturing fluid mixture required to achieve the selected at least one behavior, preparing the fracturing fluid mixture having the determined properties; and injecting the fracturing fluid mixture into the reservoir under the determined reservoir conditions, such that the mixture exhibits the desired behavior during the fracturing operation. The determined properties include a mole fraction of natural gas in the mixture.

Abstract: A downhole disconnect device for disconnecting an intervention tool string from a wireline, includes: a tubular body having a first part directly or indirectly coupleable to the wireline and a second part connectable directly or indirectly to an intervention tool string; an actuator for disconnecting the second part of the tubular body from the first part of the tubular body; at least one sensor to detect when the tool string is stuck in use and to produce an output signal accordingly; a controller configured to receive the output signal and selectively operate the actuator accordingly; and a power source. The tubular body is adapted to house the actuator, sensor, controller and power source and the device further comprises a timer configured to delay operation of the actuator by a predetermined time on receipt of the output signal from the sensor. There is also a method of operating the downhole disconnect device.

Abstract: The present disclosure relates to downhole tools, including downhole valves, which actuate via a pressure differential created across a shifting element having one or more pressure surfaces isolated from fluid, and fluid pressure, flowing through the interior flowpath. Embodiment downhole tools of the present disclosure may actuate in response to, among other signals, fluid pressure in the interior flowpath of the tool and fluid pressure communicated to a pressure surface of the shifting sleeve from the exterior of the tool. Certain embodiments may also have an outlet connector whereby fluid pressure from the downhole tool may be communicated to its exterior, including to additional tools in the tubing strings via flowlines connecting the two tools. Isolation of the shifting element from the interior flowpath may be accomplished using a frangible, shiftable, degradable or other members which may be moved from a closed state to an open state in response to fluid conditions in the interior flowpath.

Abstract: A polyamide-poly(phenylene ether) composition includes, based on the total weight of the composition, 35 to 80 weight percent of polyamide, and 20 to 65 weight percent of a poly(phenylene ether). The polyamide-poly(phenylene ether) composition is utilized in a variety of methods, including methods applicable to the oil and gas industry.

Abstract: Systems, program product, and methods for monitoring linearity of a down-hole pumping system assembly during deployment within a bore of a casing of a well positioned to extract hydrocarbons from a subterranean reservoir and selecting an optimal operational position for the down-hole pumping system assembly within the bore of the casing, are provided. Various embodiments of the systems allow an operator to ensure that a motor and pump of a down-hole pumping system assembly are installed in an optimal position in a well by ensuring alignment across the pump stages casing and motor casing. The system includes a groove extending along an outer surface of a housing of the pumping system assembly, and an optical sensing fiber mounted in the groove.

Abstract: Disclosed are sand control screens and completion assemblies that receive, retain, and protect control lines during installation and operation thereof. One disclosed completion assembly includes a base pipe, at least one screen jacket positioned around the base pipe and operable to prevent an influx of particulate matter of a predetermined size therethrough, a control line housing arranged uphole from the at least one screen jacket and having a fiber optic splicing block disposed therein, the at least one fiber optic splicing block being communicably coupled to a control line that extends uphole from the control line housing, and one or more hydraulic conduits arranged longitudinally between the at least one screen jacket and the base pipe and extending from the control line housing.

Abstract: A method of conducting multiple stage treatments. The method includes running a string into a borehole. The string having at least a first sleeve assembly and a second sleeve assembly. The first sleeve assembly in a position closing a port in the string; communicating from a radial exterior of the string or from a location downhole of the first and second sleeve assemblies to a first electronic trigger of the first sleeve assembly to trigger the first sleeve assembly into moving longitudinally relative to the string to open the port. Performing a treatment operation through the port; communicating from the radial exterior of the string or from a location downhole of the first and second sleeve assemblies to a second electronic trigger of the second sleeve assembly to trigger the second sleeve assembly into moving longitudinally relative to the string to close the port.

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: An electrochemical sensor of a downhole tool positionable in a wellbore penetrating a subterranean formation is provided. The downhole tool has a flowline to receive downhole fluid. The electrochemical sensor includes a bulkhead carried by the downhole tool, a membrane exposed to the downhole fluid in the flowline, and an electrochemical cell supported by the bulkhead about the membrane. The electrochemical cell includes a plurality of cell sensors, at least one cell electrode, and a sensing solution. The plurality cell sensors include an analyte sensor, a temperature sensor, and a pH sensor. The sensing solution is reactive to certain analytes in the downhole fluid to generate electrical signals measurable by the plurality of cell sensors whereby parameters of chemicals in the downhole fluid may be measured.

Abstract: A method is disclosed in which an electrical conductivity of a treatment fluid is measured with one or more sensor at various instants of time. The method is further performed by generating one or more signals indicative of the electrical conductivity of the treatment fluid and transmitting the one or more signals to a computer system. The method is further performed by analyzing the one or more signals to determine a phase change in the treatment fluid based upon a positive or negative change in the electrical conductivity of the treatment fluid from a predetermined electrical conductivity range.

Abstract: A method of treating a subsurface formation includes circulating at least one molten salt through at least one conduit of a conduit-in-conduit heater located in the formation to heat hydrocarbons in the formation to at least a mobilization temperature of the hydrocarbons. At least some of the hydrocarbons are produced from the formation. An electrical resistance of at least one of the conduits of the conduit-in-conduit heater is assessed to assess a presence of a leak in at least one of the conduits.

Abstract: A device including a lower assembly (30) and a cable (32) for deploying the lower assembly (30) in the well (12). The lower assembly (30) includes a pyrotechnic system (72), and a firing assembly further including a module (86) for controlling a power battery (88) and a power module (150). The control module (86) includes arming means (112; 158) of the power module (150) capable of connecting the power battery (88) to the power module (150) upon receiving an electrical arming signal transmitted through the cable (32). It includes means (114; 160) for triggering the pyrotechnic system (72) capable of connecting the power module (150) to the pyrotechnic system (72), upon receiving a distinct electrical triggering signal posterior to the arming signal.

Abstract: Example systems described herein to perform downhole fluid analysis include a depressurizer to be positioned downhole in a geological formation to depressurize a formation fluid in the geological formation. In such example systems, the depressurization of the formation fluid is to cause bubbles to nucleate in the formation fluid. Such example systems also include an imaging processor to be positioned downhole in the geological formation. In such example systems, the imaging processor is to capture imaging data associated with the formation fluid and to detect nucleation of the bubbles in the formation fluid based on the imaging data. Such example systems further include a controller to report measurement data via a telemetry communication link to a receiver to be located outside the geological formation. In such example systems, the measurement data includes a bubble point of the formation fluid calculated based on the detected nucleation of the bubbles.

Abstract: This disclosure describes formulations and methods for remediating subterranean-formed metal-polymer complexes in wells in subterranean formations. In one embodiment, the method includes injecting a metal-polymer complex remediation mixture containing a metal complexing agent into a subterranean formation adjacent to a well at a pressure below the fracture pressure of the formation. A sufficient contact time is allowed and then the metal-polymer complex remediation mixture is pumped from the subsurface. This has been shown to remediate polymer-containing, subterranean-formed metal-polymer complexes in shale formations. Without being held to a particular theory it appears that the metal complexing agent is forming metal complexes with the metals in the complexes, and particularly divalent metal ions. This removal of naturally occurring metals may be un-crosslinking and causing the metal-polymer complexes to go into solution, thereby removing the blockages caused by the metal-polymer complexes.

Abstract: A system, method and computer readable medium for determining a feature in a wellbore is disclosed. A distributed temperature sensing system is disposed along the wellbore. A thermal perturbation is induced along the wellbore. A profile is determined of temperature change in response to the applied thermal perturbation using the distributed temperature sensing system. The feature of the wellbore is determined using the measured temperature profile.

Abstract: An object launching apparatus for a well has a housing, a flow mandrel, and a cage. The flow mandrel is disposed in the housing's internal chamber, and a flow passage in the mandrel communicates flow from the housing's inlet to the mandrel's flow port, which in turn communicates with the housing's outlet. The cage is disposed in the internal chamber and defines pockets for holding the objects. A motor and shaft move the cage in the housing relative to the mandrel's flow port so the cage's pockets can be selectively positioned in communication between the mandrel's flow port and the housing's outlet. This allows any of the object(s) held in the positioned pocket to be launched into the flow to the well. Preferably, the motor rotates the shaft so the cage can ride linearly along the shaft's thread and the cage can rotate through a cammed engagement with the housing.

Abstract: The present invention relates to an electrical power distribution method for distributing power between two or more operating units of a wireline tool string downhole performing at least one operation.

Abstract: Methods for communicatively coupling components at down-hole locations within a wellbore include introducing first and second cables through which signals are transmissible into the wellbore. Terminal ends of the cables are coarsely aligned by coupling connector housings associated with the cables within the wellbore. The terminal ends are then finely aligned by activating motors to move at least one of the terminal ends within the connector housings until a signal of sufficient strength is transmissible between the first and second cables.

Abstract: Methods of acquiring viscosity of a downhole fluid in a wellbore penetrating a subterranean formation is provided. The downhole fluid is measurable by a vibrating wire viscometer positionable in the wellbore. The method involves acquiring a signal of the downhole fluid from the viscometer, generating an initial estimate of the viscosity parameter based on measured viscosity signal parameters and by selectively adjusting the viscosity signal, and generating final estimates of the viscosity parameters by performing Kalman filtering on the initial estimates.

Abstract: Systems and methods for optimal spacing of horizontal wells that maximizes coverage of a predetermined area within an irregular boundary by the horizontal wells.

Abstract: A fingerboard latch assembly includes a latch configured for operational engagement with a fingerboard for lockingly retaining at least one tubular to the fingerboard. The latch is movable within a range of motion extending from at least a locked position to an unlocked position. A positioner operatively engaged with the latch is communicably couplable to a process control network (PCN), and is sized and shaped for receipt within a latch channel of the fingerboard. The positioner is configured to move the latch within the range of motion in response to signals received from the PCN, to capture position data for the latch, including the position of the latch at a plurality of points within the range of motion, and to communicate the captured position data to the PCN.

Abstract: A system for use with a well having multiple zones can include multiple well screens which filter fluid flowing between a tubing string and respective ones of the zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the tubing string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the well screens. A tubing string for use in a subterranean well can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen.

Abstract: Temperature is measured in a shut-in wellbore and rates of temperature change in depth intervals within productive layers and in depth intervals adjacent to the productive layers are determined. Areas are selected in the depth intervals within the productive layers wherein the rate of temperature change is significantly higher than the rate of change in the depth intervals adjacent to the productive layers. A numerical model of temperature change in the shut-in wellbore is created taking into account a filtration effect of a reservoir fluid on the rate of the temperature change in the shut-in wellbore. The measurement results are compared with the numerical modeling results, and their best match is used for determining a fluid filtration velocity in the selected areas in the depth intervals within the productive layers.

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: A method and system for monitoring well operations are provided. Acceleration data is generated from vibration signals collected from a well and the data is processed to indicate a well condition such as the actuation of a device and the movement and location of an actuation device.

Abstract: A managed bulk drilling system that employs a guide wire for ranging and crosswell telemetry. Some system embodiments include multiple drilling assemblies operating in the vicinity of a reference well that contains an electrical cable. The electrical cable is coupled to a surface control system. The control system uses the electrical cable as part of an antenna to receive uplink signals from the drilling assemblies and to broadcast down-link signals to the drilling assemblies. The uplink signals can include position data and the downlink signals can include individual steering commands to adjust the trajectories of each drilling assembly. The cable can also generate a guidance field for the drilling assemblies to detect and follow.

Abstract: A wellbore y-block junction comprises a first bore channel, a second bore channel, a deflector selectable to a neutral position, to a first bore channel selected position, and to a second bore channel selected position, a radio receiver, and a controller, wherein the controller is configured to command the deflector position to one of the neutral position, the first bore channel selected position, or the second bore channel selected position based on an input from the radio receiver.