公开(公告)号：US20210388722A1

公开(公告)日：2021-12-16

申请号：US17460923

申请日：2021-08-30

Applicant: Schlumberger Technology Corporation

Inventor： Hadrien Dumont ,  Christopher Harrison ,  Youxiang Zuo ,  Christopher Albert Babin ,  Li Chen ,  Vinay K. Mishra ,  German Garcia ,  Abhishek Agarwal ,  Matthew T. Sullivan

IPC: E21B49/10 ,  E21B47/07

Abstract: Methods for obtaining in-situ, multi-temperature measurements of fluid properties, such as saturation pressure and asphaltene onset pressure, are provided. In one example, a sample of formation fluid is obtained using a downhole acquisition tool positioned in a wellbore in a geological formation. The downhole acquisition tool may be stationed at a first depth in the wellbore that has an ambient first temperature. While stationed at the first depth, the downhole acquisition tool may test a first fluid property of the sample to obtain a first measurement point at approximately the first temperature. The downhole acquisition tool may be moved to a subsequent station at a new depth with an ambient second temperature, and another measurement point obtained at approximately the second temperature. From the measurement points, a temperature-dependent relationship of the first fluid property of the first formation fluid may be determined.

公开(公告)号：US10858935B2

公开(公告)日：2020-12-08

申请号：US14164991

申请日：2014-01-27

Applicant: Schlumberger Technology Corporation

Inventor： Adriaan Gisolf ,  Youxiang Zuo ,  Ryan Sangjun Lee ,  Jonathan Leonard

IPC: E21B49/08

Abstract: Implementations of the present disclosure relate to apparatuses, systems, and methods for determining when a well cleanup process has established developed flow and then extrapolating out modeled fluid parameter values to determine parameter values for a formation fluid. The model fluid parameter values may be modeled using a power law function having a specified exponent value.

公开(公告)号：US10738606B2

公开(公告)日：2020-08-11

申请号：US16411845

申请日：2019-05-14

Applicant: Schlumberger Technology Corporation

Inventor： Youxiang Zuo ,  Kang Wang ,  Adriaan Gisolf ,  Ryan Sangjun Lee ,  Oliver C. Mullins ,  Shu Pan

IPC: E21B49/08 ,  G01N33/28

Abstract: A method includes identifying linearly behaving data within obtained data associated with fluid obtained from a subterranean formation. Shrinkage factor is determined based on the linearly behaving data. A function relating GOR data of the obtained fluid with the determined shrinkage factor is determined. A first linear relationship between optical density (OD) data of the obtained fluid and the function is determined. A second linear relationship between density data of the obtained fluid and the function is determined. An oil-based mud (OBM) filtrate contamination property of OBM filtrate within the obtained fluid based on the first linear relationship is determined. A native formation property of native formation fluid within the obtained fluid based on the second linear relationship is determined. A volume fraction of OBM filtrate contamination within the obtained fluid based on the OBM filtrate contamination property and the native formation property is estimated.

公开(公告)号：US10577928B2

公开(公告)日：2020-03-03

申请号：US14867262

申请日：2015-09-28

Applicant: Schlumberger Technology Corporation

Inventor： Kang Wang ,  Youxiang Zuo ,  Ryan Sangjun Lee ,  Adriaan Gisolf

IPC: E21B49/08

Abstract: A method includes operating a downhole acquisition tool in a wellbore in a geological formation. The wellbore or the geological formation, or both contains a fluid that includes a native reservoir fluid of the geological formation and a contaminant. The method also includes receiving a portion of the fluid into the downhole acquisition tool, measuring a fluid property of the portion of the fluid using the downhole acquisition tool, and using the processor to estimate a fluid property of the native reservoir fluid based on the measured fluid property of the portion of the fluid and a regression model that may predict an asymptote of a growth curve. The asymptote corresponds to the estimated fluid property of the native formation fluid, and the regression model includes a geometric fitting model other than a power-law model.

公开(公告)号：US10352161B2

公开(公告)日：2019-07-16

申请号：US14975704

申请日：2015-12-18

Applicant: Schlumberger Technology Corporation

Inventor： Youxiang Zuo ,  Adriaan Gisolf ,  Kang Wang ,  Ryan Sangjun Lee

IPC: E21B49/10 ,  E21B47/12 ,  E21B49/08

Abstract: A downhole tool operable to pump a volume of contaminated fluid from a subterranean formation during an elapsed pumping time while obtaining in-situ, real-time data associated with the contaminated fluid. The contaminated fluid includes native formation fluid and oil-based mud (OBM) filtrate. A shrinkage factor of the contaminated fluid is determined based on the in-situ, real-time data. The contaminated fluid shrinkage factor is fit relative to pumped volume or pumping time to obtain a function relating the shrinkage factor with pumped volume or elapsed pumping time. A shrinkage factor of the native formation fluid is determined based on the function. A shrinkage factor of the OBM filtrate is also determined. OBM filtrate volume percentage is determined based on the shrinkage factor of the native formation fluid and the shrinkage factor of the OBM filtrate.

公开(公告)号：US10294784B2

公开(公告)日：2019-05-21

申请号：US14956338

申请日：2015-12-01

Applicant: Schlumberger Technology Corporation

Inventor： Adriaan Gisolf ,  Kai Hsu ,  Yong Chang ,  Youxiang Zuo ,  Ryan Sangjun Lee ,  Ashers Partouche

IPC: E21B49/08 ,  E21B49/10 ,  G01N1/14 ,  E21B47/12

Abstract: A method includes operating a downhole acquisition tool including a guard probe and a sample probe in a wellbore that contains a fluid that includes a native reservoir fluid and a contaminant. The method also includes receiving a first portion of fluid into the guard probe and a second portion of fluid into the sample probe, estimating a contamination level of the first or second portions based on a fluid property of the respective first and second portions, determining an initial guard flow rate of the first portion, determining an initial sample flow rate of the second portion, using a processor to adjust a guard flow rate of the second portion over pump time after the contamination level of the first portion is at or below a contamination level threshold, and adjust a sample flow rate of the first portion based on the adjusted guard flow rate and total flowrate.

公开(公告)号：US20180171791A1

公开(公告)日：2018-06-21

申请号：US15837612

申请日：2017-12-11

Applicant: Schlumberger Technology Corporation

Inventor： Julian Pop ,  Cosan Ayan ,  Adriaan Gisolf ,  Juan Miguel La Retta Marin ,  Hua Yu ,  Lei Jiang ,  Youxiang Zuo

IPC: E21B49/10 ,  E21B47/06 ,  E21B49/00 ,  G01V99/00

CPC classification number: E21B49/10 ,  E21B33/12 ,  E21B47/06 ,  E21B49/00 ,  E21B2049/085 ,  G01V99/00 ,  G01V99/005

Abstract: Apparatus and methods for obtaining initial settings of station-specific parameters descriptive of wellbore/formation properties specific to downhole pressure test stations, and obtaining initial settings of station-shared parameters descriptive of petrophysical properties of petrophysically unique formation zones. A pressure transient model of the zones is obtained by regression utilizing the pressure data of each station and the initial settings of the station-specific and station-shared parameters. The regression analytically determines a model value of at least one of the station-specific parameters and the station-shared parameters.

公开(公告)号：US20180087378A1

公开(公告)日：2018-03-29

申请号：US15822293

申请日：2017-11-27

Applicant: Schlumberger Technology Corporation

Inventor： Hadrien Dumont ,  Youxiang Zuo ,  Beatriz E. Barbosa

IPC: E21B49/10 ,  E21B47/06 ,  G01V9/00

Abstract: The present disclosure relates to methods and apparatus for determining a viscosity-pressure profile of downhole fluid by measuring the viscosity at several different pressures during a sampling operation. According to certain embodiments, the viscosity may be measured at different times during a sampling operation and used to generate the viscosity-pressure profile. For example, the viscosity may be measured at the beginning of pumping, during filling of a sample chamber, during a pressure-build up period, and while retracting the probe. The measured viscosities may then be employed to determine a profile that represents the change in viscosity that occurs with pressure.

公开(公告)号：US20170370214A1

公开(公告)日：2017-12-28

申请号：US15193519

申请日：2016-06-27

Applicant: Schlumberger Technology Corporation

Inventor： Kang Wang ,  Youxiang Zuo ,  Younes Jalali

IPC: E21B49/08

Abstract: Apparatus and methods for obtaining first properties of a fluid, such as by estimating a second property of the fluid based on the first properties using a machine learning algorithm, propagating a first uncertainty of the first properties to a second uncertainty of the second property, generating an expected phase envelope of the fluid based on the second property, and generating a deviation phase envelope of the fluid based on the second uncertainty.

公开(公告)号：US20170254792A1

公开(公告)日：2017-09-07

申请号：US15599515

申请日：2017-05-19

Applicant: Schlumberger Technology Corporation

Inventor： Adriaan Gisolf ,  Youxiang Zuo ,  Ronald E. G. van Hal ,  Jeffrey Crank

IPC: G01N33/28 ,  E21B49/10 ,  G01N30/88 ,  E21B49/08

CPC classification number: G01N33/2823 ,  E21B49/087 ,  E21B49/10 ,  E21B2049/085 ,  G01N30/88 ,  G01N33/28 ,  G01N2030/8854

Abstract: Methods are provided for reservoir analysis. In some embodiments, a reservoir may be analyzed by obtaining abundance ratios at a first measurement station and a second measurement station and determining an abundance ratio trend. Abundance ratios at a third measurement station may be obtained and plotted versus depth with the previously obtained abundance ratios. A change in the abundance ratio trend may be identified and result in further investigation of the reservoir. If the abundance ratio is unchanged, additional abundance ratios may be obtained and plotted versus depth to further evaluate the abundance ratio trend. Methods for reservoir analysis using fluid predictions with and without offset well information are also provided.