Method to determine cement sheath failure risk under cyclic loads using real-time downhole deformation data

Patent metadata

Field	Value
Publication number	US-12516598-B2
Application number	US-202418678565-A
Country	US
Kind code	B2
Filing date	May 30, 2024
Priority date	May 30, 2024
Publication date	Jan 6, 2026
Grant date	Jan 6, 2026

Abstract

A method of performing a wellbore servicing operation may include: obtaining a measurement of steady state creep rate () within a cement sheath associated with a wellbore while performing the wellbore servicing operation in the wellbore; determining a number of cycles to failure (Nf) of the cement sheath using a cement material fatigue model wherein the cement material fatigue model has an input of steady state creep rate (); adjusting at least one operational parameter of the wellbore servicing operation in response to the determined number of cycles to failure (Nf) to form adjusted operational parameters; and performing the wellbore B servicing operation at the adjusted operational parameters.

First claim

What is claimed is:

1 . A method of performing a wellbore servicing operation comprising:
obtaining a measurement of steady state creep rate ( ) within a cement sheath associated with a wellbore while performing the wellbore servicing operation in the wellbore using a wellbore servicing fluid; determining a number of cycles to failure (N f ) of the cement sheath using a cement material fatigue model wherein the cement material fatigue model has an input of steady state creep rate ( ); adjusting at least one of a rate, a pressure, a density, a temperature, or a combination thereof of the wellbore servicing fluid in response to the determined number of cycles to failure (N f ); and performing the wellbore servicing operation at the rate, the pressure, the density, the temperature, or a combination thereof.

2 . The method of claim 1 wherein the wellbore servicing operation comprises at least one operation selected from the group consisting of a drilling operation, a fracturing operation, a perforating operation, an acidizing operation, a cementing operation, an enhanced oil recovery operation, a water flooding operation, a polymer flooding operation, a carbon dioxide injection operation, and combinations thereof.

3 . The method of claim 1 wherein the wellbore servicing operation includes introducing at least one servicing fluid selected from the group consisting of a fracturing fluid, a perforating fluid, a cementitious fluid, a sealant fluid, a remedial fluid, a drilling fluid, a spacer fluid, a gelation fluid, a polymeric fluid, an aqueous fluid, an oleaginous fluid, an emulsion fluid, and combinations thereof.

4 . The method of claim 1 wherein the measurement of steady state creep rate ( ) is obtained using a downhole sensing technique selected from the group consisting of a fiber optic cable, a strain gauge, a piezo resistive sensor, an acoustic sensor, sonic sensor, ultrasonic sensor and combinations thereof.

5 . The method of claim 1 wherein the cement material fatigue model has a linear form, a polynomial form, an exponential form, or any combination thereof.

6 . The method of claim 1 wherein the cement material fatigue model has a form of:

N
f

=

A
×

ε
ss

′
⁢

f
⁡
(
comp
)

where N f is total number of cycles to failure, A is a model constant, and composition function ƒ (composition) is a function that determines an effect of composition on fatigue response of a cement.

7 . The method of claim 6 wherein the cement material fatigue model has a linear form, a polynomial form, an exponential form, or any combination thereof.

8 . The method of claim 6 wherein the cement material fatigue model is a function of at least one of water to pozzolan ratio water/pozzalon in the cement sheath, concentration of elastomer in the cement sheath, mass fraction of portland cement in the cement sheath, weighting agent concentration in the cement sheath, and foam quality in the cement sheath.

9 . The method of claim 1 wherein adjusting at least one operational parameter reduces a stress exerted on the cement sheath.

10 . A method of performing a wellbore servicing operation comprising:
determining a remaining number of cycles for the wellbore servicing operation in a wellbore; obtaining a measurement of steady state creep rate ( ) within a cement sheath associated with the wellbore while pumping a wellbore servicing fluid into the wellbore; determining number of cycles to failure (N f ) of the cement sheath using a cement material fatigue model wherein the cement material fatigue model has an input of steady state creep rate ( ); comparing the number of cycles to failure and the remaining number of cycles; and
adjusting at least one of a rate, a pressure, a density, a temperature, or a combination thereof of the wellbore servicing fluid such that the number of cycles to failure is greater than the remaining number of cycles.

11 . The method of claim 10 wherein the wellbore servicing operation comprises at least one operation selected from the group consisting of a drilling operation, a fracturing operation, a perforating operation, an acidizing operation, a cementing operation, an enhanced oil recovery operation, a water flooding operation, a polymer flooding operation, a carbon dioxide injection operation, and combinations thereof.

12 . The method of claim 10 wherein the wellbore servicing fluid comprises at least one fluid selected from the group consisting of a fracturing fluid, a perforating fluid, a cementitious fluid, a sealant fluid, a remedial fluid, a drilling fluid, a spacer fluid, a gelation fluid, a polymeric fluid, an aqueous fluid, an oleaginous fluid, an emulsion fluid, and combinations thereof.

13 . The method of claim 10 wherein the measurement of steady state creep rate ( ) is obtained using a downhole sensing technique selected from the group consisting of a fiber optic cable, a strain gauge, a piezo resistive sensor, an acoustic sensor, a sonic sensor, an ultrasonic sensor, and combinations thereof.

14 . The method of claim 10 wherein the cement material fatigue model has a form of:

N
f

=

A
×

ε
ss

′
⁢

f
⁡
(
comp
)

where N f is total number of cycles to failure, A is a model constant, and composition function ƒ (composition) is a function that determines an effect of composition on fatigue response of a cement.

15 . The method of claim 14 wherein the cement material fatigue model is a function of at least one of water to pozzolan ratio water/pozzalon in the cement sheath, concentration of elastomer in the cement sheath, mass fraction of portland cement in the cement sheath, weighting agent concentration in the cement sheath, and foam quality in the cement sheath.

16 . The method of claim 14 wherein the cement material fatigue model has a linear form, a polynomial form, an exponential form, or any combination thereof.

17 . The method of claim 10 wherein adjusting at least one operational parameter reduces a stress exerted on the cement sheath.

18 . A method of performing a wellbore servicing operation comprising:
introducing a fracturing fluid into a wellbore penetrating a subterranean formation at a rate and a volume sufficient to create or extend at least one fracture within the subterranean formation, wherein the wellbore comprising a cement sheath; determining a remaining number of fracturing stages for the wellbore servicing operation; obtaining a measurement of steady state cree

Assignees

• Halliburton Energy Services Inc

Inventors

• Jandhyala Siva Rama Krishna
• Devera Giorgio

Classifications

• E21B21/08 Primary

  Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure (valve arrangements therefor E21B21/10) · CPC title

• E21B43/26

  by forming crevices or fractures · CPC title

• E21B2200/20

  Computer models or simulations, e.g. for reservoirs under production, drill bits · CPC title

• E21B47/005 Primary

  Monitoring or checking of cementation quality or level · CPC title