Zug, Switzerland
Zug, Switzerland
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Prior to actual use in a downhole application, gamma spectrum shape for a gamma detector can be quantified, and a relationship established between detector gain and spectrum shape. Given this relationship, the shape of a gamma spectrum measured after downhole deployment of the detector within a wellbore, for example as part of a tool in a drill string, can be quantified and compared to the pre-established relationship to determine whether the detector gain has drifted due to temperature or operating time effects. Using this relationship, a gain-affecting voltage across the detector (e.g., the photocathode voltage across the photomultiplier tube) can be adjusted to compensate for such drifts and thus to compensate for variations caused by temperature or operating time. With such compensation applied to the detector, resulting gamma spectra reliably indicate actual differences in radiation levels, thus enabling an inference of the composition of the formation at various times/depths.


Patent
Weatherford | Date: 2017-05-17

A control system comprising a tubular handling tool, comprising having a plurality of piston cylinders and a plurality of slips configured to engage a tubular string; and a volume synchronizer comprising: a first piston cylinder having a piston connected to a first rod member; a plate member connected to the first rod member; and a plurality of second piston cylinders, each having a piston connected to the plate member by a plurality of second rod members; wherein pressurized fluid supplied to the first piston cylinder moves the plate member to move each of the pistons in the second piston cylinders, thereby forcing pressurized fluid out of the second piston cylinders and simultaneously into the piston cylinders of the tubular handling tool, thereby actuating the slips into engagement with the tubular string.


Techniques and apparatus are provided for improved diagnostics of downhole dynamometer data for control and troubleshooting of reciprocating rod lift systems. A method for pump fillage determination for a reciprocating rod lift system is provided. The method generally includes measuring downhole data during a pump cycle, wherein the downhole data comprises a first plurality of data points associated with an upstroke of the pump cycle and a second plurality of data points associated with a downstroke of the pump cycle, each data point comprising a rod position value and an associated rod load value; converting the data points to non-dimensional data points, calculating non-dimensional slope values between non-dimensional data points; and determining pump fillage based, at least part, on the calculated non-dimensional slope values.


Patent
Weatherford and Amfields LP | Date: 2017-03-01

A hydraulic pumping system can include an actuator including a piston rod that displaces in response to pressure in the actuator, a seal assembly that seals about the piston rod and is exposed to the pressure in the actuator, and another seal assembly that seals about the piston rod, is exposed to pressure in a well and includes multiple separate seal cartridges, each of the seal cartridges including a dynamic seal that slidingly and sealingly engages the piston rod. Another hydraulic pumping system can include an actuator including a piston rod that displaces in response to pressure in the actuator, a seal assembly that seals about the piston rod and is exposed to the pressure in the actuator, and another seal assembly that seals about the piston rod, is exposed to pressure in a well and includes a labyrinth ring comprising multiple ring layers.


A method is disclosed of inverting three dimensional fluid property distribution. The method includes comparing a detected NMR signal with a plurality of modeled signal values derived from precomputed values of NMR signal contribution values at prechosen (T_(1), T_(2), D) value tuples; identifying one or more modeled signals satisfying domain constraints and in respect of which an objective function involving a respective detected NMR signal and a modeled signal is optimised; selecting one or more of the solutions resulting in optimised objective; and using each selected optimized solution to characterize the one or more properties of fluid in the formation. The method also includes processing the resulting solutions as e.g. graphical or tabular data. Also disclosed is apparatus for performing the method.


Patent
Weatherford | Date: 2017-01-25

In one embodiment, a tubular gripping assembly for use with a top drive to handle a tubular includes a tubular gripping tool having a mandrel and gripping elements operatively coupled to the mandrel; and a link assembly attached to the mandrel, wherein a load of the link assembly is transferred to the mandrel. In another embodiment, the tubular gripping assembly includes a swivel having selectively actuatable seals. In yet another embodiment, the tubular gripping assembly includes a thread compensator to facilitate tubular make-up. In yet another embodiment, the tubular gripping assembly includes a wedge lock release apparatus to facilitate the release of gripping elements from the tubular.


Patent
Weatherford | Date: 2017-04-05

The present disclosure relates to apparatus and methods for isolating a tool, such as a sand control screen, from axial and/or torsional loads applied to a tubular string. A sand screen assembly includes a sand control screen, a fixed-end coupling, and a free-end coupling. A first end of the sand control screen is coupled to the fixed-end coupling by a secure connection, and a second end of the sand control screen is coupled to the free-end coupling so the second end of the sand control screen is free to rotate or move axially relative to the free-end coupling.


Patent
Weatherford and Amfields LP | Date: 2017-03-01

A pumping method can include displacing a rod string with pressure applied to an actuator by a pressure source including an accumulator and a separate gas volume in communication with the accumulator. A sensor indicates whether a fluid is in the gas volume. A pumping system can include an actuator, a pump connected between the actuator and an accumulator, a hydraulic fluid contacting a gas in the accumulator, a separate gas volume in communication with the accumulator, and a sensor that detects the hydraulic fluid in the gas volume. Another pumping system can include an actuator, a pump connected between the actuator and an accumulator that receives nitrogen gas from a nitrogen concentrator assembly while a hydraulic fluid flows between the pump and the actuator, a separate gas volume in communication with the accumulator, and a sensor that detects a presence of the hydraulic fluid in the gas volume.


Patent
Weatherford | Date: 2017-02-08

The disclosure relates to a system and method for determining whether a kick or loss has occurred from a well in real time, wherein the well has a marine diverter having a rotating control device. The marine diverter system may measure flow rate in real time of a drilling fluid entering the wellbore and provide a means of measuring flow rate of the drilling fluid out of the wellbore and riser. The marine diverter system may further determine displacement and velocity of displacement of rig heave motion in real time and use the foregoing steps, given a known internal diameter of the riser and a known external diameter of a drill pipe, and employing a drilling fluid volume balance equation:


Patent
Weatherford | Date: 2017-03-08

The present invention generally relates to a pipe handling system for use with a tubular joining system (such as a welding or forging assembly) located on a drilling rig at a wellbore. In one aspect, a method of forming a string of pipe using a joining assembly at a wellbore is provided. The joining assembly includes an internal joining tool and an external joining tool. The method includes the step of picking up the pipe joint using an elevator. The method further includes the step of positioning a lower end of the pipe joint adjacent an end of a string of pipe disposed in the external joining tool. The method also includes the step of moving the internal joining tool from a first position to a second position relative to the elevator, wherein the second position is between the pipe joint and the string of pipe. The method further includes the step of forming a connection between the pipe joint and the string of pipe. The method further includes the step of gripping the pipe joint with a gripping tool and releasing the elevator from the pipe joint. Additionally, the method includes the step of lowering the pipe joint and the string of pipe into the wellbore. In another aspect, a method of forming a string of pipe using a joining assembly on a rig is provided. In a further aspect, a pipe handling system for locating a pipe joint in a joining assembly that includes an internal joining tool and an external joining tool is provided.

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