Hadrien Dumont

20170328202, Nov 16, 2017

May 12, 2017

15/594232

- Sugar Land TX, US
Hadrien Dumont - Houston TX, US
Anthony Robert Holmes Goodwin - Sugar Land TX, US
Kentaro Indo - Sugar Land TX, US
Julian Pop - Houston TX, US

E21B 49/08
G01V 8/00
G01V 9/00
E21B 49/08
E21B 49/08

A method includes operating a downhole acquisition tool in a wellbore in a geological formation. The wellbore or the geological formation, or both, contain a reservoir fluid. The method also includes receiving a portion of the reservoir fluid into the downhole acquisition tool and performing downhole fluid analysis using the downhole acquisition tool in the wellbore to determine at least one measurement associated with the portion of the reservoir fluid. The at least one measurement includes fluid density, optical density, or both. The method also includes using a processor of the downhole acquisition tool to obtain compressibility of the reservoir fluid based at least in part on the fluid density, the optical density, or both and determining a composition of the reservoir fluid based at least in part on the compressibility.

20170022809, Jan 26, 2017

Jun 15, 2016

15/183090

- Sugar Land TX, US
Hadrien Dumont - Houston TX, US
Vinay K. Mishra - Katy TX, US
Li Chen - Katy TX, US
Abhishek Agarwal - Sugar Land TX, US
Cosan Ayan - Clamart, FR

E21B 49/08
G01N 33/24
E21B 33/12

The present disclosure relates to a formation sampling method that includes disposing a downhole tool comprising a packer and an expandable probe within a wellbore. The method also includes performing pressure transient testing by setting the expandable packer and the probe to engage a wall of the wellbore and measuring a pressure response at the expandable packer and the probe while withdrawing formation fluid into the downhole tool through the expandable packer. The method further includes monitoring a contamination level of the formation fluid during the pressure transient testing, and performing formation sampling with the probe in response to determining that the monitored contamination level meets a predetermined threshold.

20160348480, Dec 1, 2016

May 26, 2016

15/165798

- Sugar Land TX, US
Kang Wang - Beijing, CN
Andrew E. Pomerantz - Lexington MA, US
Soraya S. Betancourt Pocaterra - Katy TX, US
Jerimiah Forsythe - Cambridge MA, US
Cosan Ayan - Istanbul, TR
Hadrien Dumont - Houston TX, US
Vinay Mishra - Katy TX, US
Jesus Alberto Canas - Katy TX, US
Daniel M. Tetzlaff - Houston TX, US
Anish Kumar - Katy TX, US
Vladislav Achourov - Stavanger, NO
Thomas Pfeiffer - Lagos, NG
Shu Pan - Edmonton, CA
Yi Chen - Sugar Land TX, US
Armin Kauerauf - Aachen, DE
Oliver C. Mullins - Houston TX, US

E21B 43/00
E21B 41/00
E21B 49/08

A method includes receiving first fluid property data from a first location in a hydrocarbon reservoir and receiving second fluid property data from a second location in the hydrocarbon reservoir. The method includes performing a plurality of realizations of models of the hydrocarbon reservoir according to a respective plurality of one or more plausible dynamic processes to generate one or more respective modeled fluid properties. The method includes selecting the one or more plausible dynamic processes based at least in part on a relationship between the first fluid property data, the second fluid property data, and the modeled fluid properties obtained from the realizations to identify potential disequilibrium in the hydrocarbon reservoir.

20160252454, Sep 1, 2016

Oct 3, 2014

15/027227

- Sugar Land TX, US
Hadrien Dumont - Houston TX, US
Richard Jackson - Cape Town, ZA
Ilaria De Santo - Paris, FR
Oliver C. Mullins - Houston TX, US
Cosan Ayan - Istanbul, TR

G01N 21/59
G01N 11/02
G01N 30/88
E21B 49/08

The present disclosure relates to a downhole fluid analysis method that includes withdrawing formation fluid into a downhole tool at a plurality of stations within a wellbore, analyzing the formation fluid within a fluid analyzer of a downhole tool to determine properties of the formation fluid for the plurality of stations, and developing, based on the determined properties of the formation fluid, a relationship for predicting viscosity from a measured optical density.

20160091389, Mar 31, 2016

Sep 22, 2015

14/861925

- Sugar Land TX, US
Vinay K. Mishra - Katy TX, US
Hadrien Dumont - Houston TX, US
Adriaan Gisolf - Houston TX, US
Christopher Babin - Waveland MS, US
Cosan Ayan - Istanbul, TR
Beatriz E. Barbosa - Houston TX, US

G01M 3/32
E21B 49/08

The present disclosure relates to systems and methods for determining an integrity of a sample chamber. In certain embodiments, formation fluid is collected from a subterranean formation within a sample chamber disposed in a downhole tool, the downhole tool is withdrawn from a wellbore, an estimated surface pressure of the collected formation fluid is determined, the estimated surface pressure of the collected formation fluid is compared with an actual surface pressure of the sample chamber, and the integrity of the sample chamber is determined based on the comparison of the estimated surface pressure and the actual surface pressure.

20150247942, Sep 3, 2015

Mar 2, 2015

14/635760

- Sugar Land TX, US
Hadrien Dumont - Houston TX, US
Joseph Carl Fiduk - Houston TX, US
Vinay Mishra - Katy TX, US
Youxiang Zuo - Burnaby, CA
Oliver C. Mullins - Houston TX, US

G01V 1/50
G01V 1/00

Various implementations described herein are directed to a method for assessing risks of compartmentalization. In one implementation, the method may include receiving seismic data for a formation of interest; identifying areas in the formation having a dip angle greater than about degrees; performing a plurality of downhole fluid analysis (DFA) within a wellbore around the formation having the dip angle greater than about 30 degrees to identify areas experiencing mass density inversion; and determining the areas experiencing mass density inversion by DFA as having one or more risks of compartmentalization.

20150142317, May 21, 2015

Nov 20, 2013

14/085589

- Sugar Land TX, US
Adriaan Gisolf - Houston TX, US
Ryan Lee - Sugar Land TX, US
Cosan Ayan - Istanbul, TR
Hadrien Dumont - Houston TX, US
Kang Wang - Beijing, CN
Chetankumar Desai - Sugar Land TX, US
Oliver Mullins - Houston TX, US
Beatriz Barbosa - Houston TX, US

Schlumberger Technology Corporation - Sugar Land TX

E21B 49/08

702 6

A method for performing contamination monitoring through estimation wherein measured data for optical density, gas to oil ratio, mass density and composition of fluid components are used to obtain plotting data and the plotting data is extrapolated to obtain contamination levels.

20150047835, Feb 19, 2015

Aug 14, 2014

14/460253

- Sugar Land TX, US
Orlando Gomes dos Reis Neto - Houston TX, US
Hadrien Dumont - Houston TX, US
Youxiang Zuo - Burnaby, CA
Beatriz E. Barbosa - Houston TX, US

E21B 47/00
E21B 44/00

16625001, 166 53

The present disclosure relates to determining hydrogen indexes of downhole fluids using fluid composition data. In certain embodiments, the type of the fluid, such as gas, water, or oil, may be determined downhole and used to select a method for determining the hydrogen index of the fluid. The selected method may then be employed while the tool is downhole to calculate the hydrogen index of the fluid.