Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Holdings LLC

Erik N Lee

Daniel Boyd Cooper

Roger Glen Duncan

William Albert Johnston

Jesse J Howard

A downhole tool orientation determination system to determine a radial orientation of a tool conveyed downhole into a pipe via a carrier and a method of determining a radial orientation of a tool conveyed downhole into a pipe via a carrier are described. The system includes an orientation tool conveyed downhole by the carrier that conveys the tool, and a distributed acoustic sensor (DAS). The DAS includes an optical fiber disposed axially along an outer surface of the pipe; and a processor to determine an orientation of the orientation tool with respect to the optical fiber based on a measurement by the optical fiber at different rotational positions of the orientation tool. The processor determines the radial orientation of the tool with respect to the optical fiber based on the orientation of the orientation tool with respect to the optical fiber.

DAS-based downhole tool orientation determination

A method of monitoring acoustic energy using distributed acoustic sensing. The method involves supplying a fluid flow at different pressures and sensing fluid flow characteristics in at least one location at each pressure. The data may be processed to provide a fluid resistance value related to a particular fluid flow at each location, collectively forming a fluid resistance index (FRI). The method may include following the initial fluid flow with a process flow, which may then be followed by another fluid flow. The flow characteristics of the latter fluid flow may be measured and compared with the initial fluid flow, providing a measure of the success of the process flow. In application, this method may be used to enhance downhole operations, including acid stimulation treatments.

Method for monitoring a flow using distributed acoustic sensing

A system includes a distributed acoustic sensing (DAS) optical fiber configured to be disposed with a downhole component, an interrogation device including an optical signal source configured to inject an optical signal into the DAS optical fiber and a receiver configured to detect return signals reflected from sensing locations in the fiber, and an acoustic telemetry unit configured to receive a communication from the downhole component and generate an acoustic signal having a frequency within a selected frequency range and encoded to carry the communication, the acoustic signal applied to a first section of the DAS optical fiber. The system also includes a processor configured to associate a first portion of the return signals with the first section and reproduce the communication based on the first portion, and associate a second portion of the return signals with a second section of the fiber and detect one or more acoustic events.

Communication using distributed acoustic sensing systems

An apparatus for monitoring vibration of a downhole component includes an optical fiber sensor including at least one optical fiber operably connected to an interrogation unit. The at least one optical fiber has a resonant segment that is fixedly attached to the component via attachment points on the component, the resonant segment between the attachment points being separate from the component and having a resonant frequency based at least on the length of the resonant segment.

Fiber optic vibration monitoring

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.

Monitoring fluid flow in a downhole assembly

A passive acoustic system and a method of utilizing the passive acoustic system in a subsurface borehole are discussed. The method includes disposing the passive acoustic system in the borehole, the passive acoustic system including at least one passive acoustic resonator, and monitoring a frequency of an acoustic signal at the at least one passive acoustic resonator. The passive acoustic system includes a protective tubing, a fiber optic cable disposed within the protective tubing, a fluid layer between the fiber optic cable and the protective tubing, and at least one passive acoustic resonator, the at least one passive acoustic resonator representing an area within the protective tubing having a known geometry, wherein the fluid layer affects a frequency of an acoustic signal obtained from the at least one passive acoustic resonator.

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Houston, TX, United States of America

Erik N Lee