Method for perforation clusters stimulation efficiency determination

Patent metadata

Field	Value
Publication number	US-11898443-B2
Application number	US-201817199114-A
Country	US
Kind code	B2
Filing date	Dec 6, 2018
Priority date	Dec 6, 2018
Publication date	Feb 13, 2024
Grant date	Feb 13, 2024

Abstract

A method may comprise identifying one or more pressure dissipation mechanisms that drop pressure within a fluid handling system, identifying one or more open flowpath elements, performing a matching algorithm with an information handling system, and initializing the matching algorithm with an estimate of a coefficient. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface, pumping equipment, wherein the pumping equipment is attached to the fluid supply vessel and disposed on the surface; a wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation, and a flowpath element, wherein the flowpath element fluidly couples the wellbore supply conduit to the formation.

First claim

What is claimed is:

1. A method, comprising:
conducting a pumping operation comprising pumping a treatment fluid into a subterranean formation;
creating at least one fracture in the subterranean formation;
obtaining pressure measurements from a pressure sensor during the pumping operation;
identifying one or more pressure dissipation mechanisms within a fluid handling system from at least the pressure measurements, wherein the one or more pressure dissipation mechanisms comprise a perforation resistance and a tortuosity resistance;
identifying one or more active flowpath elements from the pressure dissipation mechanisms;
performing a matching algorithm with an information handling system using the pressure dissipation mechanisms; and
initializing the matching algorithm with an estimate of a coefficient.

2. The method of claim 1 , wherein the one or more pressure dissipation mechanisms further comprise a wellbore friction or an in-situ stress.

3. The method of claim 1 , wherein the matching algorithm is a trust region reflective algorithm or a dogleg algorithm with a rectangular trust region.

4. The method of claim 1 , further comprising changing a pumping schedule.

5. The method of claim 1 , further comprising examining a pumping schedule to identify at least one period of constant operation.

6. The method of claim 1 , further comprising identifying one or more phases in which one or more flowpath elements are constant.

7. The method of claim 6 , wherein the identifying the one or more phases is performed by examining a pumping schedule, creating a probability distribution, or creating a graph of a pressure in view of a flow rate.

8. The method of claim 7 , wherein the graph of the pressure in view of the flow rate records one or more constant flow elements.

9. The method of claim 1 , further comprising dividing the one or more pressure dissipation mechanisms among one or more flowpath elements.

10. The method of claim 9 , wherein the dividing the one or more pressure dissipation mechanisms among one or more discrete elements is found with

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wherein P section is a measured or a calculated pressure drop, Q is a total flow rate, n is a number of open flowpath elements, and f is a resistance coefficient.

11. A system comprising:
a fluid handling system comprising:
a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface;
pumping equipment, wherein the pumping equipment is attached to the fluid supply vessel and disposed on the surface;
a wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation; and
a flowpath element, wherein the flowpath element fluidly couples the wellbore supply conduit to the formation;
a pressure sensor, wherein the pressure sensor obtains pressure measurements during a pumping operation; and

an information handling system configured to:
identify one or more pressure dissipation mechanisms in the fluid handling system from at least the pressure measurements, wherein the one or more pressure dissipation mechanisms comprise a perforation resistance and a tortuosity resistance;
identify one or more active flow elements from the pressure dissipation mechanisms;
perform a matching algorithm with the information handling system using the pressure dissipation mechanisms; and
initialize the matching algorithm with an estimate of a coefficient.

12. The system of claim 11 , wherein the one or more pressure dissipation mechanisms further comprise a wellbore friction or an in-situ stress.

13. The system of claim 11 , wherein the matching algorithm is a trust region reflective algorithm or a dogleg algorithm with a rectangular trust region.

14. The system of claim 11 , wherein the information handling system is further configured to change a pumping schedule.

15. The system of claim 11 , wherein the information handling system is further configured to examine a pumping schedule to identify at least one period of constant operation.

16. The system of claim 11 , wherein the information handling system is further configured to identify one or more phases in which one or more flowpath elements are constant.

17. The system of claim 16 , wherein the information handling system is further configured to examine a pumping schedule, create a probability distribution, or create a graph of a pressure in view of a flow rate.

18. The system of claim 17 , wherein the graph of the pressure in view of the flow rate records one or more constant flow elements.

19. The system of claim 11 , wherein the information handling system is further configured to divide the one or more pressure dissipation mechanisms among one or more flowpath elements.

20. The system of claim 19 , wherein the information handling system is further configured to use

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Assignees

• Halliburton Energy Services Inc

Inventors

• Swaminathan Tirumani N
• Shetty Dinesh Ananda
• Martysevich Vladimir Nikolayevich
• Ma Jianfu

Classifications

• E21B49/008 Primary

  by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor (measuring pressure E21B47/06) · CPC title

• E21B43/26

  by forming crevices or fractures · CPC title

• E21B47/06

  Measuring temperature or pressure · CPC title

• G06F17/17

  Function evaluation by approximation methods, e.g. inter- or extrapolation, smoothing, least mean square method ({G06F17/18 takes precedence } ; interpolation for numerical control G05B19/18) · CPC title