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Joel T Le

from Houston, TX
Age ~40
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Also known as:
Joel Thanh Le, Joel Kristen Le, Joel C Le, Joel T Kristen
Related to:
Legiang T NguyenTina T Le, 58T LeyDevin D Le, 51Hyeongdong Baek, 64Rick TleKristen Y Baek, 34Y T LeYoung Baek Jee, 62Danh H Nguyen, 69Liem H Nguyen, 49Peter Y BaekKatie T Le, 43
Connected to:
Aimy T Le, 33Al T Le, 45Alen D Le, 42Alena Le, 28Amanda Le, 54Ananda T Le, 38Anastasia Le, 27Angie Le, 72Anhdao Le, 45Annah M Le, 41

Joel Le Phones & Addresses

  • Houston, TX
  • 8803 Norham Dr, Houston, TX 77083 (281) 933-3331

Work

Position: Craftsman/Blue Collar

Education

Degree: High school graduate or higher

Emails

d***[email protected]

Resumes

Resumes

Joel Le Photo 1

Account Executive, Registered Nurse

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Industry:
Security And Investigations
Work:
Your Quality Healthcare
Account Executive, Registered Nurse
Education:
University of Houston 2004 - 2008
Skills:
House
Joel Le Photo 2

Marketing Professor And Director Of Executive Education, Sales Excellence Institute, University Of Houston

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Location:
Houston, Texas Area
Industry:
Higher Education

Publications

Us Patents

System And Technique To Quantify A Fracture System

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US Patent:
20100256964, Oct 7, 2010
Filed:
Apr 7, 2009
Appl. No.:
12/419799
Inventors:
Donald W. Lee - Houston TX, US
Jose Ignacio Adachi - Houston TX, US
Lennert David den Boer - Calgary, CA
Joel Herve Le Calvez - Farmers Branch TX, US
Assignee:
Schlumberger Technology Corporation - Houston TX
International Classification:
G06G 7/48
US Classification:
703 10
Abstract:
A technique includes generating a fracture network model to characterize a fracture system in a reservoir that is associated with a well. The generation of the model includes constraining the model based at least in part on identified naturally occurring fractures and microseismic measurements that were acquired during a fracturing operation that was conducted in the well.

True Particle Velocity Wavefield Processing In Fiber Optics - Particle Motion Sensor Hybrid Array

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US Patent:
20220307895, Sep 29, 2022
Filed:
Mar 24, 2021
Appl. No.:
17/211429
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Richmond TX, US
International Classification:
G01H 9/00
G01V 8/16
G01V 1/22
Abstract:
Systems and methods may be used to reconstruct particle velocity wavefields from coupling-calibrated fiber-optic data that subsequently enables physically valid construction of the particle velocity wavefields for a hybrid sensor array including both fiber-optic and particle motion sensors. These systems and methods may be used in a variety of borehole geophysical applications, such as structure and reservoir imaging, impedance inversion, attenuation tomography, micro-seismic fracture imaging, focal mechanism analysis, and so on. The systems and methods may also be used in other applications such as geothermal and CO2 storage monitoring.

Full Automation Of High-Resolution Interval Velocity Estimation For Check-Shot And Other Vertical Seismic Profile- Type Datasets

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US Patent:
20220244416, Aug 4, 2022
Filed:
Feb 2, 2021
Appl. No.:
17/165239
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Richmond TX, US
International Classification:
G01V 1/30
Abstract:
Embodiments presented provide for a fully automated method of high-resolution interval velocity estimation for vertical seismic profile-type data.

Fiber Measurements For Fluid Treatment Processes In A Well

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US Patent:
20200032640, Jan 30, 2020
Filed:
Oct 2, 2017
Appl. No.:
16/337396
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Houston TX, US
Brian D. Clark - Houston TX, US
International Classification:
E21B 47/10
E21B 47/06
G01V 1/22
G01V 1/40
Abstract:
A method includes running a cable into a first wellbore. A fluid diversion process is initiated in the first wellbore. A first downhole measurement is captured in the first wellbore using the cable or a first sensor coupled thereto concurrently with or after the fluid diversion process. An additional measurement is captured concurrently with capturing the first downhole measurement. The first downhole measurement and the additional measurement are compared or combined. A location where fluid is flowing through perforations in the first wellbore is determined based upon the combining or comparing the first downhole measurement and the additional measurement.

Fiber Optic Measurements To Evaluate Fluid Flow

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US Patent:
20190264556, Aug 29, 2019
Filed:
Oct 10, 2017
Appl. No.:
16/340825
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Houston TX, US
Brian D. Clark - Houston TX, US
International Classification:
E21B 47/10
E21B 47/06
E21B 43/26
Abstract:
A method includes varying a temperature of a treatment fluid. The treatment fluid is pumped into the first wellbore as part of a fluid diversion process or a fluid treatment process after the temperature of the treatment fluid is varied. A first downhole measurement is obtained in the first wellbore using a cable in the first wellbore or a first sensor coupled to the cable concurrently with or after the fluid diversion process or the fluid treatment process. An additional measurement is obtained concurrently with obtaining the first downhole measurement. The first downhole measurement and the additional measurement are combined or compared. A location where the treatment fluid is flowing through perforations in the first wellbore is determined based upon the combining or comparing the first downhole measurement and the additional measurement.

Borehole Trajectory Via Multi-Component Borehole Seismic Receiver

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US Patent:
20180187542, Jul 5, 2018
Filed:
Jul 4, 2016
Appl. No.:
15/741778
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Houston TX, US
International Classification:
E21B 47/022
G01V 1/16
E21B 49/00
Abstract:
A method can include receiving an estimated spatial location of a three-component receiver in a borehole; receiving a plurality of spatial locations of sources of seismic energy; receiving incident angles for the three-component receiver at the estimated spatial location for the plurality of spatial locations of the sources of seismic energy; computing orientations for the three-component receiver based at least in part on the incident angles; minimizing an error function for the orientations; and, based at least in part on the minimizing, determining one or more deviation survey parameter values that specify at least a portion of a trajectory for the borehole.

Treatment Based On Fiber Cable Sensor Data

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US Patent:
20180100388, Apr 12, 2018
Filed:
Oct 10, 2016
Appl. No.:
15/289628
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Houston TX, US
International Classification:
E21B 47/10
G01H 9/00
E21B 43/26
E21B 43/267
E21B 49/00
Abstract:
A method can include, during a treatment process, receiving vibration data acquired over a length of a fiber cable sensor disposed in a well that includes perforations; filtering the vibration data as to traveling waves to generate filtered data; analyzing the filtered data to generate fluid flow information; and adjusting the treatment process based at least in part on the fluid flow information.

Crosswell Microseismic System

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US Patent:
20180095184, Apr 5, 2018
Filed:
Sep 30, 2016
Appl. No.:
15/282096
Inventors:
- Sugar Land TX, US
Joel Herve Le Calvez - Houston TX, US
Herve Denaclara - Stafford TX, US
International Classification:
G01V 1/28
G01V 1/42
Abstract:
A method can include receiving seismic data responsive to stimulation of an anisotropic formation via a well disposed in the formation; receiving crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locating a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and rendering the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.
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Joel T Le from Houston, TX, age ~40 Get Report