Halliburton Energy Services, Inc.

Schlumberger Technology Corporation

Other

Maxim Nikolayevich Yushko

Julian J Pop

Kentaro Indo

Michael Dewayne Finke

Pralay K Das

Tullio Moscato

Svetozar Dimitrov Simeonov

Sepand Ossia

Tudor Ioan Palaghita

Zeynep Alpman

Alexis Petit

Kim A Hodgson

Ramon Hernandez Marti

Stephen D Mason

Bruce MacKay

Aspects of the subject technology relate to a sensor for a downhole tool. The downhole tool can include a collar and a sensor. The sensor can be secured to the collar for measuring one or more operational characteristics of the downhole tool during operation of the downhole tool. The sensor can include a substrate. The sensor can also include a plurality of strain gauges disposed on the substrate. The plurality of strain gauges can be configured to measure axial strains and torsional strains on the collar for measuring the one or more operational characteristics of the downhole tool.

Integrated collar sensor for measuring health of a downhole tool

Aspects of the subject technology relate to a sensor for a downhole tool. The downhole tool can include a collar and a sensor. The sensor can be secured to the collar for measuring one or more operational characteristics of the downhole tool during operation of the downhole tool including the performance characteristics of a drill motor. The sensor can include a substrate. The sensor can also include a plurality of strain gauges disposed on the substrate. The plurality of strain gauges can be configured to measure axial strains and torsional strains on the collar for measuring the one or more operational characteristics of the downhole tool.

Integrated collar sensor for measuring performance characteristics of a drill motor

Integrated collar sensor for a downhole tool

Integrated collar sensor for measuring mechanical impedance of the downhole tool

A method for sampling a downhole formation fluid includes pumping formation fluid into the flowline of a downhole sampling tool While pumping, a saturation pressure of the formation fluid is measured. The pumping rate is adjusted such that the fluid pressure in the flowline remains above a threshold saturation pressure.

Flowline saturation pressure measurements

A method for sampling a downhole formation fluid includes pumping formation fluid into the flowline of a downhole sampling tool, measuring a saturation pressure of the formation fluid in the flowline while pumping, and adjusting the pumping rate such that the fluid pressure in the flowline remains within a predetermined threshold above the measured saturation pressure.

Flowline saturation pressure measurement

A method for sampling a downhole formation fluid includes pumping formation fluid into the flowline of a downhole sampling tool. The method can also include measuring a saturation pressure of the formation fluid in the flowline while pumping. The method can also include adjusting the pumping rate such that the fluid pressure in the flowline remains within a predetermined threshold above the measured saturation pressure.

A method for sampling a downhole formation fluid that includes pumping formation fluid into the flowline of a downhole sampling tool. The method also includes measuring a saturation pressure of the formation fluid in the flowline while pumping, and adjusting the pumping rate such that the fluid pressure in the flowline remains within a predetermined threshold above the measured saturation pressure.

An apparatus with a reduced dead volume associated with sampling, comprising: a sample container configured to store a fluid, a sample line configured to transport the fluid from a first sampling area to a second area in the sample container, at least one valve in the sample line, the valve configured to selectively range from a closed configuration to an open configuration, and a flow restrictor configuration placed in the sample line, the flow restrictor configured to minimize the dead volume for the sample container.

Apparatus, system and method for reducing dead volume in a sample container

A method includes measuring electrical conductivity of a treatment fluid with one or more sensors 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.

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Houston, TX, United States of America

Maxim Nikolayevich Yushko