Preserving wellbore integrity during carbon dioxide injection

Patent metadata

Field	Value
Publication number	US-2024193315-A1
Application number	US-202218062659-A
Country	US
Kind code	A1
Filing date	Dec 7, 2022
Priority date	Dec 7, 2022
Publication date	Jun 13, 2024
Grant date	—

Abstract

Embodiments presented provide for a method to negate debonding of the casing from a cement in a wellbore. In one embodiment, the cement around the casing is set with a sufficiently large residual compressive stress, preventing the deboning.

First claim

What is claimed is:

1 . A method of designing a wellbore with a cement residual compressive stress layer around a casing, comprising:
obtaining data related to an open hole log for a wellbore in a field;
performing a simulation for injection of a fluid within the field with a desired mass flow rate, a given surface temperature and anticipated designed perforations, the simulation computing downhole temperature on the wellbore;
inferring densities of a mud and a cement slurry used within the field from a first mud specification and a first cement specification to be used with the wellbore;
estimating a value of cement shrinkage (γ c );
computing a possible extent for shrinkage of material around the wellbore based upon the value of cement shrinkage (γ c );
evaluating the wellbore with the loading to determine if a case of plane stress or plane strain model governs the radial deformation of the wellbore, wherein:
for a case of the plane stress governing the wellbore based upon the loading method steps of:
setting a maximum brine height for the wellbore;
calculating a plane stress coefficient value;
calculating a value of stress and radial deformation for the wellbore;
calculating a value of a height of slurry for the wellbore;
reevaluating brine height if slurry height is at the bounds;

are accomplished; and
for a case of plane strain governing the wellbore based upon the loading;
setting a maximum brine height for the wellbore;
calculating a plane strain coefficient value;
calculating a value of plane stress for the wellbore;
calculating a value of a height of slurry for the wellbore;
reevaluating brine height if slurry height is at the bounds;

determining if a collapse of a casing occurs for the loading based upon the loading either of the plane stress or plane strain cases, wherein in an event of the collapse, one of a second casing specification and a second cement specification is chosen and a second simulation is run; and
writing all input and calculated parameters to a non-volatile memory.

2 . The method according to claim 1 , wherein the fluid is carbon dioxide.

3 . The method according to claim 1 , wherein the value of γ c is obtained experimentally.

4 . The method according to claim 1 , further comprising:
setting a new maximum brine height based, at least in part, on a height of a slurry.

5 . The method according to claim 1 , further comprising:
displaying input and calculated parameters on a monitor.

6 . The method according to claim 1 , wherein in the case of plane stress, a value of stress and radial strain is estimated.

7 . The method according to claim 1 , wherein in the case of plane strain, a value of stress and radial strain is estimated.

8 . The method according to claim 1 , wherein the obtaining data related to an open hole log for the wellbore in the field includes a formation temperature.

9 . The method according to claim 1 , wherein the obtaining data related to an open hole log for the wellbore includes specifying a mass flow rate of fluid to be pumped downhole and determining downhole fluid temperature.

10 . A method of designing a wellbore with a cement residual compressive stress layer around a casing, comprising:
obtaining data related to an open hole log for a wellbore in a field;
performing a simulation for injection of a fluid within the field with a desired mass flow rate, a given surface temperature and anticipated designed perforations, the simulation computing the downhole temperature on the wellbore;
inferring densities of a mud and a cement slurry used within the field from a first mud specification and a first cement specification to be used with the wellbore;
estimating a value of cement shrinkage γ c
computing a possible extent for shrinkage of material around the wellbore based upon the value of cement shrinkage (γ c );
evaluating the wellbore if a case of plane stress or plane strain model governs the wellbore deformation, wherein:
for a case of the plane stress governing the wellbore based upon the loading method steps of:
setting a maximum brine height for the wellbore;
calculating a plane stress coefficient value;
calculating a value of stress and radial strain for the wellbore;
calculating a value of a height of slurry for the wellbore;
recalculating brine height if the slurry height is at the bounds are accomplished; and

for a case of plane strain governing the wellbore based upon the loading;
setting a maximum brine height for the wellbore;
calculating a plane strain coefficient value;
calculating a value of stress and radial strain for the wellbore;
calculating a value of a height of slurry for the wellbore;
recalculating brine height if the slurry height is at the bounds

determining if a collapse of a casing occurs for the loading based upon the loading either of the plane stress or plane strain case values, wherein in an event of the collapse, one of a second casing specification and a second cement specification is chosen and a second simulation is run; and
writing all input and calculated parameters to a non-volatile memory.

11 . The method according to claim 8 , wherein the fluid is carbon dioxide.

12 . The method according to claim 8 , wherein the value of γ c is obtained experimentally.

13 . The method according to claim 1 , further comprising:
displaying input and calculated parameters on a monitor.

14 . The method according to claim 1 , wherein in the case of plane stress, values of stress and radial strain are estimated.

15 . The method according to claim 1 , wherein in the case of plane strain, a value of stress and radial strain are estimated.

16 . The method according to claim 1 , wherein the obtaining data related to an open hole log for the wellbore in the field includes a formation temperature.

17 . The method according to claim 1 , wherein the obtaining data related to an open hole log for the wellbore includes specifying a mass flow rate and determining the downhole temperature of the fluid to be pumped downhole.

Assignees

• Schlumberger Technology Corp

Inventors

• Ramakrishnan Terizhandur S
• Morrell Daniel

Classifications

• E21B41/0064

  Carbon dioxide sequestration (storing fluids in porous layers B65G5/005) · CPC title

• G06F2113/08

  Fluids · CPC title

• G06F2119/14

  Force analysis or force optimisation, e.g. static or dynamic forces · CPC title

• G06F2119/08

  Thermal analysis or thermal optimisation · CPC title

• G06F30/28

  using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD] · CPC title