公开(公告)号：US10316656B2

公开(公告)日：2019-06-11

申请号：US14697382

申请日：2015-04-27

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：US10228325B2

公开(公告)日：2019-03-12

申请号：US15027227

申请日：2014-10-03

Applicant: Schlumberger Technology Corporation

Inventor： Youxiang Zuo ,  Hadrien Dumont ,  Richard Jackson ,  Ilaria De Santo ,  Oliver C. Mullins ,  Cosan Ayan

IPC: G01N21/59 ,  E21B49/08 ,  E21B49/10 ,  G01N11/00 ,  G01N11/02 ,  G01N30/88

Abstract: 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.

公开(公告)号：US10190396B2

公开(公告)日：2019-01-29

申请号：US14927305

申请日：2015-10-29

Applicant: Schlumberger Technology Corporation

Inventor： Yi Chen ,  Kang Wang ,  Oliver C. Mullins ,  Youxiang Zuo

IPC: E21B43/00 ,  E21B49/08 ,  G06F17/10

Abstract: A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

公开(公告)号：US09664032B2

公开(公告)日：2017-05-30

申请号：US15063267

申请日：2016-03-07

Applicant: Schlumberger Technology Corporation

Inventor： Oliver C. Mullins ,  Shahid A. Haq

IPC: E21B47/024 ,  E21B49/00 ,  E21B49/08 ,  E21B7/04 ,  E21B47/022 ,  G01S15/89 ,  G01V3/20 ,  G01V3/28 ,  G01V3/30 ,  G01V8/10

CPC classification number: E21B47/024 ,  E21B7/04 ,  E21B47/022 ,  E21B49/00 ,  E21B49/08 ,  G01S15/89 ,  G01V3/20 ,  G01V3/28 ,  G01V3/30 ,  G01V8/10

Abstract: Method of drilling a well, including one method comprising determining a first value indicative of a relative position of a geological bed boundary with respect to a drilling assembly, determining a second value indicative of an optical property of a formation fluid proximate the drilling assembly, and controlling a well trajectory based on the first and second value.

公开(公告)号：US09581014B2

公开(公告)日：2017-02-28

申请号：US14164940

申请日：2014-01-27

Applicant: Schlumberger Technology Corporation

Inventor： Yi Chen ,  Youxiang Zuo ,  Oliver C. Mullins

IPC: G01N7/00 ,  E21B47/06 ,  G01N33/28

CPC classification number: E21B47/06 ,  E21B49/088 ,  E21B49/10 ,  G01N33/2823

Abstract: A method for predicting asphaltene onset pressure in a reservoir is provided. In one embodiment, the method includes performing downhole fluid analysis of formation fluid via a downhole tool at a measurement station at a first depth in a wellbore and determining an asphaltene gradient for the formation fluid at the measurement station. Asphaltene onset pressure for a second depth in the wellbore may then be predicted based on the downhole fluid analysis and the determined asphaltene gradient. Additional methods, systems, and devices are also disclosed.

Abstract translation: 提供了一种预测储层中沥青质起始压力的方法。 在一个实施例中，该方法包括在井眼的第一深度的测量站处经由井下工具对地层流体进行井下流体分析，并且确定测量站处的地层流体的沥青质梯度。 然后可以基于井下流体分析和确定的沥青质梯度来预测井筒中第二深度的沥青质起始压力。 还公开了附加的方法，系统和装置。

公开(公告)号：US20170016321A1

公开(公告)日：2017-01-19

申请号：US15279828

申请日：2016-09-29

Applicant: Schlumberger Technology Corporation

Inventor： Shu Pan ,  Youxiang Zuo ,  Yi Chen ,  Kang Wang ,  Oliver C. Mullins

IPC: E21B49/10

CPC classification number: E21B49/10 ,  E21B43/00 ,  E21B49/088 ,  E21B2049/085 ,  G01V7/00 ,  G01V11/00 ,  G01V2210/6165 ,  G01V2210/644 ,  G01V2210/663

Abstract: A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

Abstract translation: 使用井下工具，地面设备和/或远程设备来获得与地下烃储存器，其中容纳的流体和/或从其获得的流体相关联的数据。 从数据中识别至少一个条件，指示存储在容器中的流体中的密度反演存在。 从数据中估计储存器中所含的流体成分的分子大小。 基于数据和分子大小生成密度反演的模型。 密度反演模型用于估计密度倒置量，深度和从储层内形成密度反演以来经过的时间。 基于数据和密度倒置量，深度和经过时间生成密度反演的重力感应电流的模型。

公开(公告)号：US20160168985A1

公开(公告)日：2016-06-16

申请号：US14966689

申请日：2015-12-11

Applicant: Schlumberger Technology Corporation

Inventor： Soraya S. Betancourt-Pocaterra ,  Dariusz STRAPOC ,  Ivan Fornasier ,  Vinay K. Mishra ,  Jesus Alberto Canas ,  Oliver C. Mullins

IPC: E21B49/00

CPC classification number: E21B49/005

Abstract: Various implementations directed to analyzing a reservoir using fluid analysis are provided. In one implementation, a method may include determining mud gas logging (MGL) data based on drilling mud associated with a wellbore traversing a reservoir of interest. The method may also include determining first downhole fluid analysis (DFA) data based on a first reservoir fluid sample obtained at a first measurement station in the wellbore. The method may further include determining predicted DFA data for the wellbore based on the first DFA data. The method may additionally include determining second DFA data based on a second reservoir fluid sample obtained at a second measurement station in the wellbore. The method may further include analyzing the reservoir based on a comparison of the MGL data and a comparison of the second DFA data to the predicted DFA data.

Abstract translation: 提供了用于使用流体分析来分析储层的各种实施方式。 在一个实施方案中，方法可以包括基于与穿过感兴趣的储层的井眼相关联的钻井泥浆来确定泥浆气体测井（MGL）数据。 该方法还可以包括基于在井筒中的第一测量站处获得的第一储层流体样品来确定第一井下流体分析（DFA）数据。 该方法还可以包括基于第一DFA数据确定井眼的预测DFA数据。 该方法可以另外包括基于在井筒中的第二测量站处获得的第二储层流体样品来确定第二DFA数据。 该方法还可以包括基于MGL数据的比较和第二DFA数据与预测的DFA数据的比较来分析储层。

公开(公告)号：US09243493B2

公开(公告)日：2016-01-26

申请号：US13886605

申请日：2013-05-03

Applicant: Schlumberger Technology Corporation

Inventor： Kai Hsu ,  Kentaro Indo ,  Oliver C. Mullins ,  Peter S. Hegeman

IPC: E21B47/10 ,  E21B49/08

CPC classification number: E21B49/087 ,  E21B47/102 ,  E21B49/08 ,  E21B2049/085

Abstract: A system and method for determining at least one fluid characteristic of a downhole fluid sample using a downhole tool are provided. In one example, the method includes performing a calibration process that correlates optical and density sensor measurements of a fluid sample in a downhole tool at a plurality of pressures. The calibration process is performed while the fluid sample is not being agitated. At least one unknown value of a density calculation is determined based on the correlated optical sensor measurements and density sensor measurements. A second optical sensor measurement of the fluid sample is obtained while the fluid sample is being agitated. A density of the fluid sample is calculated based on the second optical sensor measurement and the at least one unknown value.

公开(公告)号：US20150363520A1

公开(公告)日：2015-12-17

申请号：US14762828

申请日：2014-01-13

Applicant: SCHLUMBERGER TECHNOLOGY CORPORATION

Inventor： William J. Bailey ,  Benoit Couet ,  Peter Kaufman ,  Oliver C. Mullins

IPC: G06F17/50 ,  E21B49/08

CPC classification number: G01V99/005 ,  E21B49/00 ,  E21B49/08 ,  E21B49/087 ,  E21B49/10 ,  G01V11/00

Abstract: A method for deriving VOI for a hydrocarbon-bearing reservoir fluid model based on DFA data (“true fluid model”) versus an “incorrect fluid model” includes calculating first, second and third objective functions that are based on NPV(s) of simulated production by a reservoir simulator with different configurations. For the first objective function, the simulator is configured with the incorrect fluid model and control variables that are optimized to derive a first group of control variable values. For the second objective function, the simulator is configured with the true fluid model and the first group of control variable values. For the third objective function, the simulator is configured with the true fluid model and control variables that are optimized to identify a second group of control variable values. The objective functions can be deterministic, or can include statistics that account for uncertainty. A visualization of such results with uncertainty is also described.

Abstract translation: 基于DFA数据（“真实流体模型”）与“不正确的流体模型”相比，用于导出含烃储层流体模型的VOI的方法包括计算基于模拟的NPV的第一，第二和第三目标函数 通过不同配置的油藏模拟器生产。 对于第一个目标函数，模拟器配置有不正确的流体模型和被优化以得到第一组控制变量值的控制变量。 对于第二个目标函数，模拟器配置有真实流体模型和第一组控制变量值。 对于第三目标函数，模拟器配置有真实的流体模型和被优化以识别第二组控制变量值的控制变量。 目标函数可以是确定性的，也可以包括考虑不确定性的统计学。 还描述了具有不确定性的这种结果的可视化。

公开(公告)号：US20150247942A1

公开(公告)日：2015-09-03

申请号：US14635760

申请日：2015-03-02

Applicant: Schlumberger Technology Corporation

Inventor： Andrew Emil Pomerantz ,  Hadrien Dumont ,  Joseph Carl Fiduk ,  Vinay Mishra ,  Youxiang Zuo ,  Oliver C. Mullins

IPC: G01V1/50 ,  G01V1/00

CPC classification number: G01V1/50 ,  E21B49/00 ,  G01V1/003 ,  G01V11/00 ,  G01V2210/644 ,  G01V2210/663

Abstract: 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 30 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.

Abstract translation: 本文描述的各种实现涉及用于评估分区的风险的方法。 在一个实现中，该方法可以包括接收用于感兴趣的形成的地震数据; 识别地层中具有大于约30度的倾角的区域; 在具有大于约30度的倾角的地层周围的井筒内执行多个井下流体分析（DFA）以识别经历质量密度反演的区域; 并确定经历DFA的质量密度反演的区域具有一个或多个划分的风险。