Patents by Inventor John Philip GRANVILLE
John Philip GRANVILLE has filed for patents to protect the following inventions. This listing includes patent applications that are pending as well as patents that have already been granted by the United States Patent and Trademark Office (USPTO).
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Patent number: 11536117Abstract: Fluid characteristics of a well fluid can be monitored. For example, a computing device can receive sensor signals from an acoustic sensor positioned on a well tool. The sensor signals can indicate characteristics of acoustic emissions generated by a well fluid impacting the well tool. The computing device can determine an acoustic signature for the well fluid using the characteristics of the acoustic emissions. The computing device can determine a difference between the acoustic signature a baseline acoustic-signature for the well fluid. The computing device can determine one or more fluid characteristics of the well fluid using the difference between the acoustic signature and the baseline acoustic-signature. The computing device can transmit a notification indicating the one or more fluid characteristics.Type: GrantFiled: October 8, 2018Date of Patent: December 27, 2022Assignee: Halliburton Energy Services, Inc.Inventors: John Philip Granville, Etienne Samson
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Patent number: 11511829Abstract: An autonomous loading/unloading system and method for transferring material includes: a buoy for releasing onto water; a messenger line coupled to the buoy for being pulled; a carrier line loop coupled to the messenger line for being pulled, where a payload is coupled to the carrier loop for transferring the material to or from an unmanned ship; a fetch/release platform to fetch or release the payload from or onto the water; a loading/unloading dock for the payload; a plurality of line guides for guiding the carrier loop; and a platform-to-payload interconnect for autonomous loading or unloading of the material from/to the payload.Type: GrantFiled: September 14, 2021Date of Patent: November 29, 2022Assignee: RAYTHEON BBN TECHNOLOGIES CORP.Inventors: William Bowles Coney, John Philip Granville, Edin Insanic
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Patent number: 11499418Abstract: An apparatus includes a central body having a longitudinal axis and a first extended member attached to the central body, wherein the first extended member extends away from the longitudinal axis. The apparatus also includes a first mechanically sensitive sensor mechanically coupled to the first extended member.Type: GrantFiled: December 10, 2018Date of Patent: November 15, 2022Assignee: Halliburton Energy Services, Inc.Inventors: John Philip Granville, Terry Don Bickley
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Publication number: 20220268959Abstract: Apparatus, methods, and systems for determining acoustic velocity behind casing or tubing in a subterranean wellbore. A method may include obtaining a plurality of waveform data sets corresponding to a plurality of propagation path regimes and obtaining a total wavefield across the receiver array. The method may also include determining a Green's function representing each of the plurality of propagation path regimes and determining a noise wavefield by convolving the Green's functions and a known transmitted pressure signal corresponding to the plurality of waveform data sets. The method may also include generating a reduced-noise wavefield by subtracting the noise wavefield from the total wavefield and estimating the acoustic velocity of a formation behind the casing or tubing from the reduce-noise wavefield.Type: ApplicationFiled: August 30, 2019Publication date: August 25, 2022Applicant: HALLIBURTON ENERGY SERVICES, INC.Inventors: Kristoffer Thomas WALKER, John Philip GRANVILLE, Chung CHANG
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Patent number: 11414982Abstract: A method and system for determining a deployment profile of a fiber optic cable. The method may comprise disposing a fiber optic cable into a tubular structure, opening and closing a valve to form a pressure pulse, wherein the pressure pulse travels within the tubular structure, sensing the pressure pulse within the tubular structure with the fiber optic cable and at least one pressure transducer, recording data from the pressure pulse with the fiber optic cable and the at least one pressure transducer, and sending the data to an information handling system from the fiber optic cable. A well measurement system may comprise a tubular structure, a fiber optic cable, a valve, and an information handling system, wherein the information handling system is configured to open and close the valve to form a pressure pulse and record data from the pressure pulse.Type: GrantFiled: April 24, 2018Date of Patent: August 16, 2022Assignee: Halliburton Energy Services, Inc.Inventors: John Philip Granville, Mark Elliott Willis
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Publication number: 20220009596Abstract: An autonomous loading/unloading system and method for transferring material includes: a buoy for releasing onto water; a messenger line coupled to the buoy for being pulled; a carrier line loop coupled to the messenger line for being pulled, where a payload is coupled to the carrier loop for transferring the material to or from an unmanned ship; a fetch/release platform to fetch or release the payload from or onto the water; a loading/unloading dock for the payload; a plurality of line guides for guiding the carrier loop; and a platform-to-payload interconnect for autonomous loading or unloading of the material from/to the payload.Type: ApplicationFiled: September 14, 2021Publication date: January 13, 2022Inventors: William Bowles Coney, John Philip Granville, Edin Insanic
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Patent number: 11161572Abstract: An autonomous loading/unloading system and method for transferring material includes: a buoy for releasing onto water; a messenger line coupled to the buoy for being pulled; a carrier line loop coupled to the messenger line for being pulled, where a payload is coupled to the carrier loop for transferring the material to or from an unmanned ship; a fetch/release platform to fetch or release the payload from or onto the water; a loading/unloading dock for the payload; a plurality of line guides for guiding the carrier loop; and a platform-to-payload interconnect for autonomous loading or unloading of the material from/to the payload.Type: GrantFiled: June 1, 2020Date of Patent: November 2, 2021Assignee: Raytheon BBN Technologies Corp.Inventors: William Bowles Coney, John Philip Granville, Edin Insanic
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Patent number: 11112519Abstract: Disclosed are systems and methods for selecting modes and frequencies of interest in a slowness-frequency map of sonic logging information. These include measuring, by a sonic logging tool, sonic data within a borehole, determining a frequency range for a selected mode of the sonic data, determining a slowness range for the selected mode of the sonic data, applying the frequency range and the slowness range to the sonic data to select a subset of data from the sonic data, processing the selected subset of data.Type: GrantFiled: March 28, 2017Date of Patent: September 7, 2021Assignee: HALLIBURTON ENERGY SERVICES, INC.Inventors: Ruijia Wang, Chung Chang, John Philip Granville, Baichun Sun
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Publication number: 20210215035Abstract: An apparatus includes a central body having a longitudinal axis and a first extended member attached to the central body, wherein the first extended member extends away from the longitudinal axis. The apparatus also includes a first mechanically sensitive sensor mechanically coupled to the first extended member.Type: ApplicationFiled: December 10, 2018Publication date: July 15, 2021Inventors: John Philip Granville, Terry Don Bickley
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Patent number: 10989047Abstract: A method and system for receiving calibration information including a first power spectral density (PSD) value and a first sand concentration value at a particular frequency. Data is collected in a liquid flow at the particular frequency at a first depth in a downhole environment. A second power spectral density (PSD) value is then determined for the data in the liquid flow at the particular frequency. The second PSD value being compared with the first PSD value. Sand can also be determined to be present in the liquid flow when the second PSD value is greater than the first PSD value by a predefined threshold. A second sand concentration value of the sand present in the liquid flow being quantified based on the first sand concentration value.Type: GrantFiled: May 10, 2019Date of Patent: April 27, 2021Assignee: HALLIBURTON ENERGY SERVICES, INC.Inventors: John Philip Granville, Atchyuta Ramayya Venna, Batakrishna Mandal
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Publication number: 20210032979Abstract: A method and system for determining a deployment profile of a fiber optic cable. The method may comprise disposing a fiber optic cable into a tubular structure, opening and closing a valve to form a pressure pulse, wherein the pressure pulse travels within the tubular structure, sensing the pressure pulse within the tubular structure with the fiber optic cable and at least one pressure transducer, recording data from the pressure pulse with the fiber optic cable and the at least one pressure transducer, and sending the data to an information handling system from the fiber optic cable. A well measurement system may comprise a tubular structure, a fiber optic cable, a valve, and an information handling system, wherein the information handling system is configured to open and close the valve to form a pressure pulse and record data from the pressure pulse.Type: ApplicationFiled: April 24, 2018Publication date: February 4, 2021Applicant: Halliburton Energy Services, Inc.Inventors: John Philip Granville, Mark Elliott Willis
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Publication number: 20200355070Abstract: Disclosed are systems and methods for receiving, by at least one processor, calibration information comprising a first power spectral density (PSD) value and a first sand concentration value at a particular frequency, collecting, by at least one processor, data in a liquid flow at the particular frequency at a first depth in a downhole environment, determining, by the at least one processor, a second power spectral density (PSD) value for the data in the liquid flow at the particular frequency, comparing, by the at least one processor, the second PSD value with the first PSD value and determining that sand is present in the liquid flow when the second PSD value is greater than the first PSD value by a predefined threshold, and quantifying, by the at least one processor, a second sand concentration value of the sand present in the liquid flow based on the first sand concentration value.Type: ApplicationFiled: May 10, 2019Publication date: November 12, 2020Applicant: HALLIBURTON ENERGY SERVICES, INC.Inventors: John Philip GRANVILLE, Atchyuta Ramayya VENNA, Batakrishna MANDAL
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Publication number: 20200355838Abstract: Systems, methods, and computer-readable media are provided for detecting sand in a production flow. An example method can include receiving acoustic field data generated by at least one acoustic sensor on a downhole tool lowered into a borehole of a production flow. The method can further include inputting the acoustic field data into an acoustic sand detection model and generating a sand flow signal based on output on the acoustic sand detection model.Type: ApplicationFiled: May 10, 2019Publication date: November 12, 2020Applicant: HALLIBURTON ENERGY SERVICES, INC.Inventors: Atchyuta Ramayya VENNA, Batakrishna MANDAL, John Philip GRANVILLE, Federico Combis LUCAS, JR.
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Patent number: 10775525Abstract: Techniques for estimating and visually presenting formation slowness are disclosed herein. The techniques include receiving acoustic signal responses from adjacent formations at a plurality of depths in a borehole environment, mapping a distribution of the acoustic signal responses at each depth according to slowness and a frequency values, determining at least one confidence interval to define a coherence threshold for the distribution of the acoustic signal responses at each depth, generating a variable density log for each depth based on the distribution of acoustic signals responses that satisfy the confidence interval for one or more frequency ranges, determining a formation slowness value for each depth based on the variable density log for the each depth, and presenting a semblance map that includes a slowness axis, a depth axis, the formation slowness value for each depth, and at least a portion of the distribution of acoustic signal responses at each depth.Type: GrantFiled: March 28, 2017Date of Patent: September 15, 2020Assignee: HALLIBURTON ENERGY SERVICES, INC.Inventors: Ruijia Wang, Chung Chang, John Philip Granville, Gary Wayne Kainer
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Publication number: 20200109612Abstract: Fluid characteristics of a well fluid can be monitored. For example, a computing device can receive sensor signals from an acoustic sensor positioned on a well tool. The sensor signals can indicate characteristics of acoustic emissions generated by a well fluid impacting the well tool. The computing device can determine an acoustic signature for the well fluid using the characteristics of the acoustic emissions. The computing device can determine a difference between the acoustic signature a baseline acoustic-signature for the well fluid. The computing device can determine one or more fluid characteristics of the well fluid using the difference between the acoustic signature and the baseline acoustic-signature. The computing device can transmit a notification indicating the one or more fluid characteristics.Type: ApplicationFiled: October 8, 2018Publication date: April 9, 2020Inventors: John Philip GRANVILLE, Etienne SAMSON
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Publication number: 20190025451Abstract: Techniques for estimating and visually presenting formation slowness are disclosed herein. The techniques include receiving acoustic signal responses from adjacent formations at a plurality of depths in a borehole environment, mapping a distribution of the acoustic signal responses at each depth according to slowness and a frequency values, determining at least one confidence interval to define a coherence threshold for the distribution of the acoustic signal responses at each depth, generating a variable density log for each depth based on the distribution of acoustic signals responses that satisfy the confidence interval for one or more frequency ranges, determining a formation slowness value for each depth based on the variable density log for the each depth, and presenting a semblance map that includes a slowness axis, a depth axis, the formation slowness value for each depth, and at least a portion of the distribution of acoustic signal responses at each depth.Type: ApplicationFiled: March 28, 2017Publication date: January 24, 2019Applicant: HALLIBURTON ENERGY SERVICES, INC.Inventors: Ruijia WANG, Chung CHANG, John Philip GRANVILLE, Gary Wayne KAINER