Christopher D Harrison

7784330, Aug 31, 2010

Oct 5, 2007

11/973218

Dan E. Angelescu - Cambridge MA, US
Hua Chen - Cambridge MA, US
Christopher Harrison - Auburndale MA, US
Matthew Sullivan - Belmont MA, US
Jacques Jundt - Newton Highlands MA, US

Schlumberger Technology Corporation - Cambridge MA

G01N 11/08

73 5409

A micro-fluidic device and methods for measuring one or more rheologic properties of a fluid. The micro-fluidic device includes a substrate and at least one cover bonded to a surface of the substrate with a fluid channel formed in at least one of the cover or the substrate. Further, the micro-fluidic device includes a first differential pressure gauge that can have a first differential pressure sensor in fluid communication with both a first pressure site and a second pressure site. Further still, the micro-fluidic device includes the first pressure site and the second pressure site that can be spaced apart by a first section of the fluid channel. Also, the micro-fluidic device includes a data processor communicatively coupled to the first differential pressure sensor, so as to receive data generated by the first differential pressure sensor.

8262909, Sep 11, 2012

Jul 15, 2009

12/503650

Dan Eugen Angelescu - Somerville MA, US
Philippe Salamitou - Paris, FR
Joyce Wong - Pasadena CA, US
Bhavani Raghuraman - Wilton CT, US
Brian Oliver Clark - Sugar Land TX, US
Christopher Harrison - Auburndale MA, US
Matthew Sullivan - Westwood MA, US
Andreas Hausot - Tokyo, JP
Florence Le Gallic de Kerizouet - Vannes, FR

Schlumberger Technology Corporation - Sugar Land TX

B01D 63/00
B01D 11/00

21032175, 2103216, 2102572, 422 10, 422 72, 422101, 1663083

A fluid separation method for performing fluid analysis of an unfiltered fluid. The fluid separation method includes providing a structure with a fluid analyzer and a power supply. Using a substrate for receiving a fluid flow stream of a multiphase mixture through a fluid sample inlet, wherein the substrate interconnects with the structure. Providing a membrane disposed across the fluid sample inlet for separating a fluid of interest from the multiphase mixture, wherein the fluid flow stream of the multiphase mixture has a shear rate that prevents a fouling of the membrane. Finally, the fluid separation method includes the substrate having fabricated channels, such that the fabricated channels are arranged substantially tangent to the fluid stream downstream of the porous membrane.

8271248, Sep 18, 2012

Apr 1, 2010

12/752967

Andrew E. Pomerantz - Lexington MA, US
Julian Zuo - Edmonton, CA
Christopher Harrison - Auburndale MA, US
Oliver C. Mullins - Ridgefield CT, US

Schlumberger Technology Corporation - Sugar Land TX

G06G 7/50
G06G 7/48

703 10

An improved method that performs downhole fluid analysis of the fluid properties of a reservoir of interest and that characterizes the reservoir of interest based upon such downhole fluid analysis.

20100269579, Oct 28, 2010

Apr 22, 2009

12/428454

JIMMY LAWRENCE - CAMBRIDGE MA, US
DAN E. ANGELESCU - Noisy le Grand Cedex, FR
CHRISTOPHER HARRISON - AUBURNDALE MA, US
TSUTOMU YAMATE - YOKOHAMA-SHI, JP
MATTHEW T. SULLIVAN - WESTWOOD MA, US
ROBERT J. SCHROEDER - NEWTOWN CT, US
RONALD E.G. VAN HAL - WATERTOWN MA, US
BHAVANI RAGHURAMAN - WILTON CT, US

SCHLUMBERGER TECHNOLOGY CORPORATION - Sugar Land TX

E21B 49/08

7315223

A gas separation and detection tool for performing in situ analysis of borehole fluid is described. The tool operates by introducing a reagent to a test sample and causing the resulting mixture to flow through a microfluidic channel where optical testing is performed. The optical testing detects a change in a characteristic of the reagent in response to expose to one or more particular substances in the test sample. The test sample may be borehole fluid, a mixture of borehole fluid and scrubbing fluid subsequently mixed with reagent, a mixture of reagent and gas separated from borehole fluid, or a mixture of scrubbing fluid and gas separated from borehole fluid which is subsequently mixed with reagent. A membrane may be employed to separate one or more target gasses from the borehole fluid.

20170370215, Dec 28, 2017

Jun 16, 2017

15/624735

- Sugar Land TX, US
Elizabeth Jennings Smythe - Cambridge MA, US
Matthew Sullivan - Westwood MA, US
Christopher Harrison - Auburndale MA, US
Hua Chen - Yokohama, JP

E21B 49/08
E21B 47/06
E21B 49/10

Apparatus and methods for obtaining a data response of a fluid as a function of pressure of the fluid, and estimating a dew point pressure of the fluid by detecting an inflection pressure, a downward curve pressure, a characteristic change pressure, and an intersection pressure of the function representative of the data response. The estimated dew point pressure of the fluid based on at least one of the inflection pressure, the downward curve pressure, the characteristic change pressure, and the intersection pressure.

20150354345, Dec 10, 2015

Jun 3, 2015

14/730189

- Sugar Land TX, US
Elizabeth Smythe - Cambridge MA, US
Matthew T. Sullivan - Westwood MA, US
Shunsuke Fukagawa - Arlington MA, US
Christopher Harrison - Auburndale MA, US

E21B 47/10
G01F 25/00
G01F 1/708

Methods and systems for determining the presence and/or rate of a flow of a fluid sample include transmitting light through the fluid sample are disclosed. The methods comprise, applying a series of thermal pulses to the fluid sample, the series comprises a time interval between each thermal pulse, detecting transmitted light using a light detector; and determining at least one of (a) whether or not the fluid is flowing and (b) a flow rate of the fluid, based on an intensity of the transmitted light corresponding to at least one time interval.

20150211984, Jul 30, 2015

Jan 28, 2014

14/166623

- Sugar Land TX, US
ANDREW E. POMERANTZ - LEXINGTON MA, US
CHRISTOPHER HARRISON - AUBURNDALE MA, US
OLIVER C. MULLINS - RIDGEFIELD CT, US

Schlumberger Technology Corporation - Sugar Land TX

G01N 21/17
G02F 1/39

A wellbore tool for determining a speed of sound of a fluid sample, such as a hydrocarbon sample or a wellbore fluid, is described herein. The wellbore tool includes a photoacoustic system for analyzing the fluid sample. The photoacoustic system includes a laser system that generates a laser pulse, an interface disposed between the fluid sample and the laser system, and an acoustic detector that receives an acoustic pulse that is generated in response to absorption of the laser pulse. The acoustic pulse is generated when the laser pulse is absorbed by the fluid sample or the interface. This acoustic pulse then moves through the fluid sample and is detected by the acoustic detector. The acoustic pulse is then used to determine a speed of sound of the fluid sample.

20140268156, Sep 18, 2014

Mar 13, 2013

13/800896

SCHLUMBERGER TECHNOLOGY CORPORATION - , US
SHUNSUKE FUKAGAWA - ARLINGTON MA, US
MATTHEW T. SULLIVAN - WESTWOOD MA, US
CHRISTOPHER HARRISON - AUBURNDALE MA, US

SCHLUMBERGER TECHNOLOGY CORPORATION - SUGAR LAND TX

G01N 21/59

356436

Method and systems for determining bubble point pressure of a fluid sample are described herein. The method includes transmitting light through the fluid sample and detecting transmitted light. The method also includes applying a series of thermal pulses to the fluid sample. The series of thermal pulses includes a time interval between each thermal pulse. The pressure of the fluid sample is varied and the bubble point pressure of the fluid sample is determined using an intensity of the transmitted light that corresponds to a time interval between the thermal pulses.