Halliburton Energy Services, Inc.

Prashant Shekhar

Abhijit Kulkarni

Gillies Alexander MacDonald

Robert James Costo, Jr

Mathew Dennis Rowe

Daniel Duncan Blue, Iii

Mohamed Saber Abouhussien

Brian Scott Cooper

Gillies Alexander Macdonald

Robert James Costo

A system includes an extraction system having an inlet channel and an outlet channel to receive fluid and to output processed fluid. The system also includes an extraction device to capture a first sample of fluid from the inlet channel, capture a second sample from the processed fluid from the outlet channel, and extract gas, liquid, or solids from the first sample and further gas, liquid, or solids from the second sample. Additionally, the system includes a gas, liquid, or solids analyzing device useable to analyze the gas, liquid, or solids to determine a first value of a chemical species of interest present in the first sample and to analyze the further gas, liquid, or solids to determine a second value of the chemical species of interest present in the second sample to determine an efficiency of the extraction system using the first value and the second value.

Measuring extraction efficiency for drilling fluid

An apparatus includes a shaker screen onto which downhole materials and fluid from a borehole are to be placed, the downhole materials a product of a downhole operation and a shaker to vibrate the shaker screen to separate the downhole materials from the fluid. The apparatus includes a radar to emit an electromagnetic wave onto the downhole materials on at least one of the shaker screen and a transit and detect a reflection of the electromagnetic wave reflected off at least a portion of the downhole materials and a device to determine a velocity of the downhole materials advancing along at least one of the shaker screen toward a discharge end of the shaker screen and the transit.

Velocity measurement of drilled cuttings on a shaker

A method includes performing a downhole operation in a borehole; capturing, during the downhole operation, downhole particles and drilling mud at the surface from the borehole into a screen of at least one shaker; shaking the screen to emit vibrations to separate the downhole particles from the drilling mud; defining a vibration limit for a normal operating condition of the at least one shaker; setting a vibration fault threshold based on the vibration limit for the normal operating condition; monitoring, using at least one sensor, the vibrations over time; and determining there is a fault condition for the shaker, in response to the vibrations exceeding the vibration fault threshold.

Shaker vibration and downhole cuttings measurement analysis and processing

A line of coherent radiation is projected on a bed on which one or more particles is located, the one or more particles flowing produced as a result of a downhole operation in the borehole. An image of the bed is captured wherein one or more particles on the bed deflect the line of coherent radiation. One or more image edges is detected based on the captured image. A subset of the one or more image edges is identified as corresponding to edges of the one or more particles, based in part on changes in intensity of the captured image. Information about the one or more particles, including information about of size, shape and volume, can be determined from the one or more image edges corresponding to the edges of the one or more particles.

Identifying a line of coherent radiation in a captured image of illuminated downhole particles

A method includes performing a downhole operation in a borehole in a formation. Downhole particles and drilling mud are captured at a surface from the borehole into a screen of a shaker during the downhole operation. Input power that comprises at least one of voltage, current, and leakage current being supplied to the shaker is monitored during operation of the shaker, it is determined whether the input power exceeds a threshold as a result of change in a load on the shaker. In response to determining that the input power exceeds the threshold as the result of change in the load on the shaker, it is determined that there is a kick condition in the borehole, where the kick condition comprises a condition in which a pressure of the formation exceeds a pressure in the borehole.

Downhole kick detection based on power monitoring of shale shaker(s)

A system for automated detection and removal of visual obstructions such as debris, fumes, or mist from the view zone of an imaging device. An autodetection algorithm runs on incoming visual data from a data acquisition (DAQ) system to determine if a visual obstruction is present. A controller initiates a dry-cleaning dual cycle (DCDC) run including a wet clean cycle and a dry clean cycle. During the wet clean cycle, a base fluid mist is distributed onto the view zone. Subsequently during the dry clean cycle, compressed air is distributed onto the view zone.

Automated debris removal

An imaging device (), laser(s) (), lag calculation, and/or volume calculations are used to determine cuttings volume per unit depth. A projected or theoretical volume can be calculated based on parameters of the borehole being drilled. At the surface of the borehole, cuttings can be captured in a shaker screen (). The volume of the cuttings can then be directly measured on the shaker screen. Deviations from a projected volume can be logged and notifications can be communicated on and/or offsite of the borehole. Additionally, size and shape of cuttings can be logged. Deviations from projected size and shape can also be logged. Various hydrocarbon recover}' operations can be altered based on results of the cuttings analysis and other indicators of improper hole cleaning. For instance, the drilling can be stopped, or a direction of the borehole can be altered.

Volume, size, and shape analysis of downhole particles

A method includes depositing, onto a shaker screen, downhole materials and fluids coming to a surface of the borehole as a result of a downhole operation. The downhole materials are separated from the fluids using the shaker screen. Using a radar, an electromagnetic wave is emitted toward a discharge end of the shaker screen or a transit downstream to the shaker. A reflection of the electromagnetic wave reflected off a portion of the downhole materials is detected. A velocity of the downhole materials advancing along the shaker screen toward the discharge end of the shaker screen or on a transit downstream to the shaker is determined. An approximate area occupied by the downhole materials on the shaker screen is determined. A volume of the downhole materials based on the velocity of the downhole materials and the approximate area occupied by the downhole materials on the shaker screen is determined.

A system for measuring drill cuttings may comprise a conveyor belt disposed below a shaker, wherein the shaker disposes the drill cuttings on to the conveyor belt, and an imaging system connected to the conveyor belt by a frame, wherein the frame positions the imaging system to form a field of view on the conveyor belt with the imaging system. The system may further include an information handling system configured to operate the shaker and the conveyor belt. A method for identifying a size of drill cuttings may comprise dropping drill cuttings on a conveyor belt from a shaker, operating the conveyor belt to move the drill cuttings through a field of view, viewing the drill cuttings in the field of view with an imaging system, and sizing the drill cuttings based at least in part on one or more calibration blocks attached to the conveyor belt.

Cuttings volume measurement away from shale shaker

A method of operating a gas extraction system includes receiving a drilling fluid sample at a flow meter via a flow meter inlet conduit and discharging the drilling fluid sample into a flow meter outlet conduit. A first inline mud valve positioned in the flow meter inlet conduit and a second inline mud valve positioned in the flow meter outlet conduit are each closed to transition the gas extraction system to a bypass flushing configuration. A bypass flow meter valve positioned in a flow meter bypass conduit is opened to divert the drilling fluid sample around the flow meter. The flow meter is then flushed with flushing fluid by opening first and second flow meter flushing valves and starting a pump to circulate the flushing fluid through the flow meter.

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Houston, TX, United States of America

Prashant Shekhar