US 11,441,422 B2Granted

Methods and systems for reservoir characterization and optimization of downhole fluid sampling

AssigneeSchlumberger Technology Corporation

InventorsMorten Kristensen, Nikita Chugunov

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Abstract

A method (and corresponding downhole tool) is provided for downhole fluid analysis of formation fluids. The downhole tool is operated to draw live fluid from the formation through the downhole tool and acquire observed sensor measurements of the live fluid (which includes filtrate contamination) that flows through the downhole tool. The observed sensor measurements are used in an inversion process that solves for a set of input parameter values of a computational model that predicts level of filtrate contamination in the live fluid that flows through the downhole tool. The set of input parameter values includes at least one endpoint value for the observed sensor measurements. The set of input parameter values solved by the inversion process can be stored and output for different applications.

Claims27

Dependent claims

A method for downhole fluid analysis of formation fluids, comprising:

using a downhole tool positioned in a wellbore that traverses a subterranean formation, operating the downhole tool to draw a live fluid from the formation through the downhole tool and acquire observed sensor measurements of the live fluid that flows through the downhole tool, wherein the live fluid includes filtrate contamination;
using the observed sensor measurements in an inversion process that solves for a set of input parameter values of a proxy model that predicts a level of filtrate contamination in the live fluid that flows through the downhole tool, wherein the set of input parameter values comprises at least one endpoint value for the observed sensor measurements, wherein the inversion process comprises using at least one objective function chosen from:
min
X
⁢
∫
V
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W
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(
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dV
,
wherein is an observed optical density, OD(x) is a predicted optical density output by the proxy model, W(V) is a weight-vector, and x is a vector of input parameters including the set of input parameter values and optical density endpoints for the live fluid and a pure filtrate;
or
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wherein is an observed optical density, OD(x) is a predicted optical density output by the proxy model, {circumflex over (ƒ)} is an observed GOR-related ƒ-function, ƒ(x) is a predicted GOR-related ƒ-function output by the proxy model, {circumflex over (b)} is an observed shrinkage factor, b(x) is a predicted shrinkage factor output by the proxy model, {circumflex over (ρ)} is an observed mass density, ρ(x) is a predicted mass density output by the proxy model, WOD(V), WCOR(V), and Wρ(V) are weight vectors, and x is a vector of input parameters including the optical density endpoints for the live fluid and a pure filtrate and one or more other input parameters;
and wherein the inversion is repeated until a stopping criteria is met for the at least one objective function;
and
storing and outputting the set of input parameter values solved by the inversion process.

118 more elements

A downhole tool configured for fluid analysis of formation fluids, the downhole tool comprising:

at least one fluid sensor that acquires observed sensor measurements of a live fluid that flows through the downhole tool, wherein the live fluid includes filtrate contamination;
and
at least one processor that is configured to use the observed sensor measurements in an inversion process that solves for a set of input parameter values of a proxy model that predicts a level of filtrate contamination in the live fluid, wherein the set of input parameter values comprises at least one endpoint value for the observed sensor measurements, wherein the at least one processor is further configured to store and output the set of input parameter values solved by the inversion process, and wherein the inversion process comprises using at least one objective function chosen from:
min
X
⁢
∫
V
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W
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)
⁢

-
O
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(
x
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
⁢
dV
,
wherein is an observed optical density, OD(x) is a predicted optical density output by the proxy model, W(V) is a weight-vector, and x is a vector of input parameters including the set of input parameters and the optical density endpoints for the live fluid and a pure filtrate;
or
min
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dV
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wherein is an observed optical density, OD(x) is a predicted optical density output by the proxy model, {circumflex over (ƒ)} is an observed GOR-related ƒ-function, ƒ(x) is a predicted GOR-related ƒ-function output by the proxy model, {circumflex over (b)} is an observed shrinkage factor, b(x) is a predicted shrinkage factor output by the proxy model, {circumflex over (ρ)} is an observed mass density, ρ(x) is a predicted mass density output by the proxy model, WOD(V), WGOR(V), and Wρ(V) are weight vectors, and x is a vector of input parameters including optical density endpoints for the live fluid and a pure filtrate and one or more other input parameters;
and wherein the inversion is repeated until a stopping criteria is met for the at least one objective function.

117 more elements

A downhole tool configured for fluid analysis of formation fluids, the downhole tool comprising:

at least one fluid sensor that acquires observed sensor measurements of a live fluid that flows through the downhole tool, wherein the live fluid includes filtrate contamination;
and
at least one processor that is configured to use the observed sensor measurements in an inversion process that solves for a set of input parameter values of a proxy model that predicts a level of filtrate contamination in the live fluid;
wherein the at least one processor is further configured to use the set of input parameter values solved by the inversion process to calibrate the proxy model, use the calibrated proxy model to determine at least one optimized rate of fluid flow through the downhole tool which minimizes a predicted remaining cleanup time required to reach a predetermined threshold contamination level, and perform real-time control of the downhole tool such that the flow rate of the live fluid drawn through the downhole tool matches the at least one optimized rate, wherein the inversion process comprises using at least one objective function chosen from:
min
X
⁢
∫
V
⁢
W
⁡
(
V
)
⁢

-
O
⁢
D
⁡
(
x
)

⁢
dV
,
wherein is an observed optical density, OD(x) is a predicted optical density output by the proxy model, W(V) is a weight-vector, and x is a vector of input parameters including the set of input parameter values and optical density endpoints for the live fluid and a pure filtrate;
or
min
X
⁢
∫
V
⁢
{
W
O
⁢
D
⁡
(
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)
⁢
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
+
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(
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)
⁢

ρ
^
-
ρ
⁡
(
x
)

}
⁢
dV
,
wherein is an observed optical density, OD(x) is a predicted optical density output by the proxy model, {circumflex over (ƒ)} is an observed GOR-related ƒ-function, ƒ(x) is a predicted GOR-related ƒ-function output by the proxy model, {circumflex over (b)} is an observed shrinkage factor, b(x) is a predicted shrinkage factor output by the proxy model, {circumflex over (ρ)} is an observed mass density, ρ(x) is a predicted mass density output by the proxy model, WOD(V), WGOR(V), and Wρ(V) are weight vectors, and x is a vector of input parameters including optical density endpoints for the live fluid and a pure filtrate and one or more other input parameters;
and wherein the inversion is repeated until a stopping criteria is met for the at least one objective function.

118 more elements

Dependencies are inferred from the claim text.

Facts

Application: 16/152,114Filed 4 Oct 2018 · us provisional application
Priority: 6 Oct 2017
Published: US 2019/0106987 A111 Apr 2019
Granted: 13 Sep 2022
Term ends: Not estimatedThe source records don’t support an estimate.

Classification5 codes

E21B 49/10
Obtaining fluid samples or testing fluids, in boreholes or wells: using side-wall fluid samplers or testers
E21B 49/084
Obtaining fluid samples or testing fluids, in boreholes or wells: with means for conveying samples through pipe to surface
E21B 49/088
Well testing, e.g. testing for reservoir productivity or formation parameters: combined with sampling
E21B 49/0875
Well testing, e.g. testing for reservoir productivity or formation parameters: determining specific fluid parameters

Family

Application62/569,172Us provisional application · filed 6 Oct 2017
US 2019/0106987 A1Pre-grant publication · published 11 Apr 2019
US 11,441,422 B2This patent

From the US filing history. Foreign family members aren’t listed.

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