Jianghui Wu from 1207 Doughty Pl, Sugar Land, TX 77479, age 53, Phone: 8322897511

System And Method For Estimating Formation Supercharge Pressure
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US Patent:

7647824, Jan 19, 2010
Filed:

Apr 19, 2007
Appl. No.:

11/737223
Inventors:

Jianghui Wu - Houston TX, US
Jaedong Lee - Katy TX, US
Matthias Meister - Niedersachsen, DE
Assignee:

Baker Hughes Incorporated - Houston TX
International Classification:

E21B 47/06
G01V 9/00
US Classification:

7315202, 702 12
Abstract:

A method of estimating a formation pressure in a wellbore is provided that in one aspect includes measuring a hydrostatic pressure at a selected location in the wellbore, and estimating supercharge pressure as a function of time using a forward model that utilizes the hydrostatic pressure and at least one property of mud in the wellbore that is a function of time. In another aspect, the method may estimate an initial formation pressure at a selected location in a wellbore by obtaining a hydrostatic pressure and at least three formation pressure measurements at three separate times at the selected location, and estimating the initial formation pressure using the hydrostatic pressure, the three pressure measurements and an internal mudcake parameter.

Apparatus And Method For Formation Testing
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US Patent:

8371161, Feb 12, 2013
Filed:

Mar 4, 2010
Appl. No.:

12/717258
Inventors:

Angus J. Simpson - Cypress TX, US
Wade H. Bullock - Montgomery TX, US
Marvin L. Raney - Pearland TX, US
Marcelo F. Civarolo - The Woodlands TX, US
Michael Shammai - Houston TX, US
Jianghui Wu - The Woodlands TX, US
Sefer B. Coskun - The Woodlands TX, US
Assignee:

Baker Hughes Incorporated - Houston TX
International Classification:

E21B 49/08
US Classification:

7315223, 166264
Abstract:

An apparatus made according to one embodiment may include a first chamber configured to receive fluid under pressure and to compress a gas in a second chamber in pressure communication with the first chamber, wherein the second chamber is configured to discharge the fluid out from the first chamber when pressure of the fluid in the first chamber is reduced.

Method And Apparatus For Predicting Petrophysical Properties From Nmr Data In Carbonate Rocks
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US Patent:

20120065888, Mar 15, 2012
Filed:

Sep 14, 2011
Appl. No.:

13/232416
Inventors:

Jianghui Wu - Sugar Land TX, US
Songhua Chen - Katy TX, US
Bo Gao - Austin TX, US
Assignee:

Baker Hughes Incorporated - Houston TX
International Classification:

G06F 19/00
G01V 3/32
US Classification:

702 8, 324303
Abstract:

An apparatus and method for determining a property of an earth formation using a radial basis function derived from a catalog of rock samples. Parameters of a Thomeer capillary pressure fitting curve are derived and used for analyzing rocks with unimodal or multimodal pore size distributions.

Predicting Sample Quality Real Time
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US Patent:

6799117, Sep 28, 2004
Filed:

May 28, 2003
Appl. No.:

10/446366
Inventors:

Mark A. Proett - Missouri City TX
Jianghui Wu - Austin TX
James M. Fogal - Houston TX
Madan Mohan Manohar - Houston TX
Assignee:

Halliburton Energy Services, Inc. - Houston TX
International Classification:

G01V 900
US Classification:

702 12
Abstract:

Systems and methods for estimating properties of fluid samples pumped from a formation through a well are described. Based upon input properties, an artificial neural network (ANN) may predict a plurality of data points, and each data point may correspond to a predicted time sample of the property of the fluid sample. Properties predicted by the ANN include sample quality or pumping pressure differential.

Modified Flow Rate Analysis
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US Patent:

20150057935, Feb 26, 2015
Filed:

Aug 22, 2013
Appl. No.:

13/973090
Inventors:

- Houston TX, US
Jianghui Wu - Sugar Land TX, US
Assignee:

Baker Hughes Incorporated - Houston TX
International Classification:

E21B 49/00
US Classification:

702 12
Abstract:

Methods, systems, devices, and products for estimating a parameter of interest of an earth formation. The method may include using a correction factor to conduct a flow rate analysis on fluid sampled from the formation via a probe contacting a wall of the borehole, wherein the correction factor compensates for total compressibility; determining at least one of: i) the product of formation porosity and total compressibility; ii) system compressibility; and iii) initial formation pressure; or determining a mobility of the formation using a slope of a linear relationship of a time-dependent pressure of the fluid with respect to a formation flow rate. The parameter of interest may be i) formation mobility or ii) formation permeability. The correction factor may be determined using formation compressibility. The correction factor may be determined using at least one of: i) gas saturation; ii) oil saturation; and iii) water saturation.