Thermal analysis of temperature data collected from a distributed temperature sensor system for estimating thermal properties of a wellbore

Patent metadata

Field	Value
Publication number	US-11920464-B2
Application number	US-202017039054-A
Country	US
Kind code	B2
Filing date	Sep 30, 2020
Priority date	Jan 31, 2020
Publication date	Mar 5, 2024
Grant date	Mar 5, 2024

Abstract

Temperature data collected from a distributed temperature sensing system may be used to prepare a temporal thermal profile of the wellbore. The temporal thermal profile may be used to determine a generalized heat transfer coefficient (k) and/or a generalized geothermal profile (Tae). The temporal thermal profile and the generalized heat transfer coefficient (k) and/or the generalized geothermal profile (Tae) may be used to estimate thermal properties of a wellbore, such as well as fluid and flow characteristics. A heat of hydration index may also be determined based on the temporal thermal profile.

First claim

What is claimed is:

1. A method comprising:
receiving data from a distributed temperature sensor system installed in a well bore, the data representative of a temporal thermal profile of the well bore;
filtering the data in the frequency domain to generate filtered data representative of the temporal thermal profile of the well bore;
determining, by one or more processors, a property or parameter associated with the well bore or well bore fluid from the filtered data based on the temporal thermal profile;
applying a model based on characteristics of with the well bore or the well bore fluid associated with the property or the parameter associated with the well bore or the well bore fluid to identify a simulated property or parameter corresponding to the property or parameter associated with the well bore or well bore fluid that is identified based on the temporal thermal profile, wherein the simulated property or parameter comprises a generalized transfer coefficient (k) of a fluid within the well bore and a generalized geothermal profile (T ae), and the model is applied based on a formula comprising:
T i+1 =(1 −kδt ) T i +kδtT ae

wherein Ti is an initial temperature, and t is time;
comparing a property or parameter to the simulated property or parameter; and
identifying an unknown property or parameter associated with the well bore or well bore fluid through an inverse model based on the comparison.

2. The method of claim 1 comprising determining at least one of a generalized transfer coefficient (k) of a fluid within the well bore or a generalized geothermal profile (T ae) of the wellbore based on the temporal thermal profile.

3. The method of claim 2 , modifying a cementing operation based on the determined generalized transfer coefficient (k) of the fluid within the wellbore or the generalized geothermal profile (T ae).

4. The method of claim 1 , wherein the fluid is cement within the wellbore.

5. The method of claim 1 , wherein at least one of a generalized transfer coefficient (k) of a fluid within the well bore, or a generalized geothermal profile (Tae) of the well bore is determined based on a model comprising advection of a fluid within the well bore.

6. The method of claim 1 , wherein at least one of the generalized transfer coefficient (k) of the fluid within the well bore, or the generalized geothermal profile (T ae) of the well bore is determined based on the model that accounts for heat generated within the wellbore.

7. The method of claim 6 , wherein the heat generated within the wellbore is generated from an exothermic reaction of a cement slurry within the well bore.

8. The method of claim 1 , wherein a property or parameter associated with the wellbore comprises a property or parameter of a fluid within the wellbore or formation surrounding the wellbore.

9. The method of claim 1 , wherein a property or parameter associated with the wellbore is selected from one or more of a wellbore geometry across depth, a static fluid profile, a pumping activity, a loss circulation, heat of hydration, a heat release activity, and combinations thereof.

10. The method of claim 1 , further comprising displaying a graph comprising depth versus a value based on the generalized transfer coefficient (k).

11. The method of claim 1 , further comprising displaying a graph comprising depth versus a value based on the generalized geothermal profile (Tae).

12. The method of claim 1 , comprising determining at least one of a generalized transfer coefficient (k) of a fluid within the well bore and a starting geothermal profile (Ta) based on the temporal thermal profile of the well bore, the geothermal profile determined after introduction of a fluid into the well bore but prior to the fluid releasing exothermic reaction heat.

13. The method of claim 1 , determining the heat of hydration by comparing the measured temperature by distributed temperature sensor system with a baseline thermal response model determined based on the generalized transfer coefficient (k) of a fluid within the well bore and the starting geothermal profile (Ta).

14. The method of claim 1 , wherein the distributed temperature sensor system is a fiber optic sensor system comprising a fiber optic cable disposed in a wellbore.

15. The method of claim 14 , wherein the fiber optic sensing system operates according to one or more of a Rayleigh backscattering, Brillouin backscattering, Raman backscattering, Fiber Bragg Grating, or Enhanced or Engineered fiber based sensing principle.

16. The method of claim 1 , wherein the fiber optic cable is provided within a cement slurry in an annulus of the well bore.

17. A system comprising:
one or more processors; and
a non-transitory memory coupled to the one or more processors, wherein the memory comprises instruction configured to cause the processors to perform operations for:
receiving data from a distributed temperature sensor system installed in a well bore, the data representative of a temporal thermal profile of the well bore;
filtering the data in the frequency domain to generate filtered data representative of the temporal thermal profile of the well bore;
determining a property or parameter associated with the well bore from the filtered data based on the temporal thermal profile obtained from a distributed temperature sensor system installed in a wellbore;
applying a model based on characteristics associated with the well bore or the well bore fluid associated with the property or the parameter associated with the well bore or the well bore fluid to identify a simulated property or parameter corresponding to the property or parameter associated with the well bore or well bore fluid that is identified based on the temporal thermal profile, wherein the simulated property or parameter comprises a generalized transfer coefficient (k) of a fluid within the well bore and a generalized geothermal profile (T ae), and the model is applied based on a formula comprising:
T i+1 =(1 −kδt ) T i +kδtT ae

wherein Ti is an initial temperature, and t is time;
comparing a property or parameter to the simulated property or parameter; and
identifying an unknown property or parameter associated with the well bore or well bore fluid through an inverse model based on the comparison.

18. The system of claim 17 , further comprising the distributed temperature sensor system installed in a well bore, the distributed temperature sensor system comprising a fiber optic cable in the wellbore.

19. The system of claim 17 , wherein the memory comprises instruction configured to cause the processors to perform operations for determining at least one of the generalized transfer coefficient (k) of the fluid within the well bore or the generalized geothermal profile (Tae) of the well bore based on the model that accounts for heat generated within the wellbore.

20. A tangible, non-transitory, computer-readable media having instructions encoded thereon, the instructions, when executed by a processor, are operable to perform operations for:
receiving data from a distributed temperature sensor system installed in a well bore, the data representative of a temporal thermal profile of the well bore;
filtering the data in the frequency domain to generate filtered data representative of the temporal thermal profile of the well bore;
determining a property or parameter associated with the well bore from the filtered data based on the temporal thermal profile;
applying a model based on characteristics associate

Assignees

• Halliburton Energy Services Inc

Inventors

• Yerubandi Krishna Babu
• Singh John Paul Bir
• Maida John L
• Jaaskelainen Mikko

Classifications

• E21B47/07 Primary

  Temperature · CPC title

• G01K1/026

  arrangements for monitoring a plurality of temperatures, e.g. by multiplexing · CPC title

• G01K11/3206

  at discrete locations in the fibre, e.g. using Bragg scattering · CPC title

• G01K11/322

  using Brillouin scattering · CPC title

• G01K11/324

  using Raman scattering · CPC title