Halliburton Energy Services, Inc.

David Bennett

Oluwatosin Ogundare

Terry Bickley

Jeremy C Nicholson

Claudio Olmi

Philippe Quero

Daniel Joshua Stark

Robert Phillip Darbe

Zhijie Sun

Philippe Prince

Srinivasan Jagannathan

Yang Yu

Graham Peter Jack

Iain James Shepherd

Chalice Young

Bo Gentry

Antonio K Acquaah

Manish Vishwanath

Systems and methods of the present disclosure relate to identifying geometric features of a conduit. A method includes controlling a flow into or out of a conduit to induce pressure waves in the conduit; measuring, with a pressure transducer, pressure responses in the conduit due to contact of the pressure waves with a geometric feature of the conduit; and identifying the geometric feature, based on the pressure responses.

Feature determination and calibration of pipeline geometry and features utilizing controlled fluid waves

Systems and methods for creating a pressure pulse within a pipeline are disclosed. The method includes isolating a barrel of a pipeline inspection gauge (PIG) station from the pipeline, pressurizing the barrel up to a selected pressure, and opening an isolation valve between the barrel and the pipeline, thereby creating the pressure pulse.

Pressure pulse generation

A method comprises generating, via a pulse generator, a first pressure pulse in a fluid in a pipe and detecting, via a transducer, a first reflected pressure pulse based on the first pressure pulse, wherein the first pressure pulse is reflected by a pipe feature to generate the first reflected pressure pulse. The method comprises generating, with the pulse generator, a second pressure pulse at a later time relative to generating the first pressure pulse, wherein timing of generating of the second pressure pulse is such that the second pressure pulse is superposed with the first reflected pressure pulse such that an amplitude of the second pressure pulse is greater than an amplitude of the first pressure pulse. The method comprises detecting, via the transducer, a second reflected pressure pulse based on the second pressure pulse, and detecting a pipe feature based on the second reflected pressure pulse.

Detection of pipe features with pressure pulses

A system can be used for generating a pressure signal in a flow path defined by a tubular. The system can include a pressure source, a valve, and a controller. The controller can output a command to control the pressure source for outputting a fluid hammer, according to the command, through the valve and into a flow path defined by a wellbore tubular. The system can be positioned external to the flow path. The system can determine, based on the reflection signal, a presence of a deposition, a blockage, or a leak within the flowline while the flowline is in operation.

Generating pressure waves in a flowline or a wellbore

A pigging tool may include a housing positionable in a pipeline. The housing may define a bypass channel that extends along an axis that is nonparallel to a longitudinal axis of the housing. An energy generation device can be positioned in the bypass channel of the housing such that fluid is receivable by the energy generation device to generate energy for the pigging tool. Further, an energy storage device may store energy generated from the energy generation device. The energy storage device may provide the pigging tool with energy to perform one or more operations in the pipeline.

Energy generation device for a pigging tool in a pipeline

A system is provided that includes a dart, a pressure sensor, and a controller communicatively coupled with the sensor. The dart is disposed in a fluidic channel. The dart has a main body and a flange extending from the main body and has a diameter greater than or equal to a diameter of the fluidic channel. When the dart translates within the fluidic channel and passes a location of a variation in the fluidic channel, the flange creates a pressure pulse. The pressure sensor measures the pressure pulse within the fluidic channel created by the dart. The controller determines the location of the variation based on the measured pressure pulse.

Method and system to determine variations in a fluidic channel

A master data acquisitions system is provided. A trigger emits a sync signal to be sensed by each of a plurality of data acquisition systems. A controller is communicatively coupled with each of the plurality of data acquisition systems. The controller receives data from each of the data acquisition systems. The data for each of the plurality of data acquisition systems include the sensed sync signal. The controller synchronizes the data from each of the plurality of data acquisition systems by aligning the sensed sync signal for each of the plurality of data acquisition systems.

Data acquisition systems

The disclosed embodiments include systems and methods for recording a pressure profile using a sensor connected to a flowline, generating a pressure pulse in the flowline by closing a valve connected to the flowline, calculating a first derivative and a second derivative of the pressure profile, and determining a parameter of the pressure pulse based on the first derivative and the second derivative of the pressure profile.

Automated determination of valve closure and inspection of a flowline

A method is provided for non-intrusively determining deposits of a fluidic channel. The method includes creating a pressure pulse in a fluidic channel. The method also includes sensing, by one or more sensors, reflections of the pressure pulse; and obtaining, from the one or more sensors, a measured pressure profile based on the sensed reflections of the pressure pulse. A processor then can determine one or more properties of the deposit in the fluidic channel based on the measured pressure profile.

Method and system for non-intrusively determining properties of deposit in a fluidic channel

A method may include: generating a signal in a conduit; measuring the signal; generating data representing a deposit in the conduit, the data being generated by a deposition identification model, wherein the deposition identification model utilizes the signal as an input; generating a treatment plan based at least in part on the data representing the deposit; and applying a chemical additive to the conduit based at least in part on the treatment plan.

Treatment of pipeline deposits

The subject technology relates to a process by which data from two downhole loggers (e.g., acoustic transducers), one at each end of a pipeline, can be used to improve the resolution of a pressure pulse system, even for slow valve operating times. For example, the process of the subject technology uses data from two transducers (e.g., acoustic transducers), instead of one transducer typically employed in traditional approaches, thereby leading to increased resolution of the deposit location and thickness. By improving the deposition estimation resolution, locating smaller deposits in a pipeline more accurately can be realized. The improved resolution in deposition estimation computations supports better decision making by providing more detailed measurement and quantification data for use in resolution of deposition buildup.

Growing community of inventors

Conroe, TX, United States of America

David Bennett