Method and apparatus for determining a fracture aperture in a wellbore

Patent metadata

Field	Value
Publication number	US-10509141-B2
Application number	US-201615234380-A
Country	US
Kind code	B2
Filing date	Aug 11, 2016
Priority date	Aug 17, 2015
Publication date	Dec 17, 2019
Grant date	Dec 17, 2019

Abstract

A method for determining a fracture aperture of a fracture aperture in a wellbore comprises measuring a resistivity of the wellbore with a downhole tool in a wellbore for obtaining an image of the wellbore. Based on the image, the method detects fractures in the wellbore, and calculates a fracture aperture of the detected fracture according to a predetermined model of the wellbore set up based on hypothesis relative to the configuration of the wellbore. Then, the method estimates a correction to the predetermined model when at least one of the hypothesis is not met, and determines an uncertainty range for the fracture aperture also using a measured parameter.

First claim

The invention claimed is:

1. A method for determining a fracture aperture of at least a fracture in a wellbore, wherein the method comprises:
Measuring a resistivity of the wellbore with a downhole tool in a wellbore for obtaining an image of the wellbore,
Detecting at least a fracture in the wellbore,
Calculating a fracture aperture of the detected fracture according to a predetermined model of the wellbore, the model being set up based on at least an hypothesis relative to the configuration of the wellbore,
Estimating a first correction to the predetermined model when a first hypothesis is not met,
Estimating a second correction to the predetermined model when a second hypothesis is not met,
Based on at least a measured parameter relative to the wellbore and on the first and second corrections, determining an uncertainty range for the fracture aperture
taking a drilling, completion or cementing action in view of the fracture aperture and the uncertainty range.

2. The method according to claim 1 , wherein the fracture aperture is calculated on the basis of the following equation:
W=c·A·R m b ·R xo 1-b   (1)

Where:
W=fracture aperture (mm);
A=excess current (μA mm/V);
R m =mud resistivity (ohm·m);
R xo =background formation resistivity (ohm·m);
b and c are parameters relative to the tool.

3. The method according to claim 1 , wherein at least an hypothesis is the following:
The response of the tool is due to a single fracture;
Fractures are perpendicular to the wellbore;
Fractures are of infinite length and constant width;
Fractures are filled with one fluid of known resistivity;
Scaling of imaging tool response to resistivity is valid;
Formation is of uniform material.

4. The method according to claim 1 , comprising determining at least a property relative to the wellbore based on the measured parameters, and obtaining the uncertainty on the basis of at least one of the property.

5. The method according to claim 4 , wherein the parameter and/or property comprise at least one of the following:
Standoff of the tool relative to the wellbore,
Dip of the fracture,
Longitudinal extent of the fracture,
Resistivity of the drilling fluid,
Resistivity of formation,
Density or particle size range of the drilling fluid.

6. The method according to claim 1 , wherein determining the uncertainty range is based on the calculated fracture aperture.

7. The method according to claim 1 , wherein estimating the first or second correction comprises at least one of the following:
Modelling a response of the tool or a configuration of the formation,
The model of the wellbore being based on at least a variable relative to the wellbore, setting a maximal error for a variable.

8. The method according to claim 1 , wherein estimating the first or second correction comprises estimating an uncertainty range as a function of at least a parameter relative to the wellbore.

9. The method according to claim 1 , wherein estimating the first or second correction comprises at least one of the following:
Modelling a current measured by the tool as a function of dip,
Modelling the measured current as a function of the fracture longitudinal extent,
Setting at least a maximal error for the resistivity of the formation and calculating a variation of the measured current and/or fracture in view of the maximal error,
Modelling a plurality of fluid fill patterns for a fracture and calculating a variation of fracture aperture in view of the plurality of fluid patterns
determining a minimum fracture aperture that may be detected by the tool in view of at least a parameter relative to the tool.

10. The method according to claim 9 , wherein at least one of the modelling of the current by the tool as a function of the dip, the modelling of the measured current as a function of the fracture longitudinal extent, the setting the maximal error of the resistivity of the formation, the modelling of plurality of fluid fill patterns and the determining a minimum fracture aperture that may be detected is performed in function of at least one parameter or property relative to the wellbore.

11. The method according to claim 10 , wherein the at least one parameter or property relative to the wellbore is a mud resistivity or a formation resistivity.

12. The method according to claim 1 , wherein the determination of uncertainty range is a real-time determination.

13. The method according to claim 1 , wherein the determination of uncertainty range comprises plotting the uncertainty range associated to the wellbore as a function of depth.

14. The method according to claim 1 , comprising calculating a corrected fracture aperture in view of the estimated first and second corrections.

15. The method of claim 1 , wherein taking a drilling, completion or cementing action comprises at least one of including an additive in the mud or in the cement or determining a perforation or completion plan.

16. An apparatus for determining a fracture aperture of at least a fracture in a wellbore, comprising:
A downhole tool comprising a resistivity sensor for measuring a resistivity of the wellbore and obtaining an image of the wellbore,
A processing system, and configured to:
i. Detect at least a fracture in a wellbore,
ii. Calculate a fracture aperture of the detected fracture according to a predetermined model of the wellbore, the model being set up based on at least an hypothesis relative to the configuration of the wellbore,
iii. Estimate a first correction to the predetermined model when a first hypothesis is not met,
iv. Estimate a second correction to the predetermined model when a second hypothesis is not met,
v. Based on at least a measured parameter relative to the tool or the borehole and on the first and second corrections, determine an uncertainty range for the fracture aperture,
vi. Take a specific drilling, completion or cementing action in view of the fracture aperture and the uncertainty range.

17. The apparatus according to claim 16 , wherein the downhole tool is a LWD or a wireline tool.

Assignees

• Schlumberger Technology Corp

Inventors

• Maeso Carlos
• Dubourg Isabelle
• Quesada Daniel

Classifications

• G01V3/24

  using AC · CPC title

• G01V3/30

  operating with electromagnetic waves · CPC title

• G01V3/20 Primary

  operating with propagation of electric current · CPC title

• G01V99/005

  Physics · mapped topic

• E21B47/0002

  Fixed Constructions · mapped topic