Analyzing sand stabilization treatments

• US 9,189,576 B2
• Filed: 03/13/2013
• Issued: 11/17/2015
• Est. Priority Date: 03/13/2013
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Kim, Sung Hyun, Fitzpatrick, Harvey Joseph Jr.
• Primary Examiner(s): Thangavelu, Kandasamy
• Application Number:
  US13/800,957
• Publication Number:
  US 20140278315A1
• Time in Patent Office: 979 Days
• US Class Current: 1/1
• CPC Class Codes: E21B 43/00 Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells applicable only to water E03B
• CPC Class Codes: E21B 43/12 Methods or apparatus for controlling the flow of the obtained fluid to or in wells E21B43/25 takes precedence; valve arrangements E21B34/00
• CPC Class Codes: G01V 3/18 specially adapted for well-logging
• CPC Class Codes: G06F 30/00 Computer-aided design [CAD]
• CPC Class Codes: G06F 30/20 Design optimisation, verification or simulation optimisation, verification or simulation of circuit designs G06F30/30
• CPC Class Codes: G06F 30/28 using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]

Abstract

In some aspects, sand stabilization treatments are analyzed. A computing system can determine a first predicted resource production output for a subterranean reservoir based on a sand stability model analysis for a native condition of the subterranean reservoir. The computing system can determine a second predicted resource production output for the subterranean reservoir based on a sand stability model analysis for a stabilization-treated condition of the subterranean reservoir. The computing system can output an economic value comparison of resource production for the native condition and the stabilization-treated condition based on the first and second predicted resource production outputs.

Claims

1. A method comprising:

determining, by a computing system, a first predicted resource production output for a subterranean reservoir based on a sand stability model analysis for a native condition of the subterranean reservoir;

determining, by the computing system, a second predicted resource production output for the subterranean reservoir based on a sand stability model analysis for a stabilization-treated condition of the subterranean reservoir; and

outputting an economic value comparison of resource production for the native condition and resource production for the stabilization-treated condition based on the first predicted resource production output and the second predicted resource production output.

2. The method of claim 1, wherein the economic value comparison includes information on a net present value of resource production for the native condition and information on a net present value of resource production for the stabilization-treated condition.

3. The method of claim 2, comprising:

calculating the net present value of resource production for the native condition based on a cost of completion under the native condition and a time value of resource production under the native condition; and

calculating the net present value of resource production for the stabilization-treated condition based on a cost of completion under the stabilization-treated condition and a time value of resource production under the stabilization-treated condition.

4. The method of claim 1, comprising analyzing, by the computing system, sensitivity of the economic value comparison to variations in input parameters used to determine the first predicted resource production output and the second predicted resource production output.

5. The method of claim 1, comprising selecting a resource production plan for the subterranean reservoir based on the economic value comparison, wherein the selected resource production plan includes production of reservoir resources under the native condition or production of reservoir resources under the stabilization-treated condition.

6. The method of claim 5, comprising initiating the resource production plan.

7. The method of claim 1, wherein

determining the first predicted resource production output includes:

determining a duration of wellbore productivity for the native condition based on the sand stability model analysis for the native condition; and

determining a resource production rate for the native condition over the duration of wellbore productivity for the native condition; and

determining the second predicted resource production output includes;

determining a duration of wellbore productivity for the stabilization-treated condition based on the sand stability model analysis for the stabilization-treated condition; and

determining a resource production rate for the stabilization-treated condition over the duration of wellbore productivity for the stabilization-treated condition.

8. The method of claim 7, wherein the duration of well bore productivity for the native condition is determined based on a predicted sand stability failure under the native condition, and the duration of well bore productivity for the stabilization-treated condition is determined based on a predicted sand stability failure under the stabilization-treated condition.

9. The method of claim 7, wherein the resource production rate for the native condition is determined based on a nodal analysis flow simulation for the native condition, and the resource production rate for the stabilization-treated condition is determined based on a nodal analysis flow simulation for the stabilization-treated condition.

10. The method of claim 9, wherein the nodal analysis flow simulation for the native condition accounts for variations in reservoir pressure over time under the native condition, and the nodal analysis flow simulation for the stabilization-treated condition accounts for variations in reservoir pressure over time under the stabilization-treated condition.

11. The method of claim 1, wherein the first predicted resource production output is based on a sand stability model analysis for the native condition of the subterranean reservoir with a mechanical sand control scheme.

12. The method of claim 11, wherein the mechanical sand control scheme includes at least one of a gravel pack, a fracture pack, or sand screens.

13. A non-transitory computer-readable medium storing instructions that, when executed by data processing apparatus, perform operations comprising:

determining a first predicted resource production output for a subterranean reservoir based on a sand stability model analysis for a native condition of the subterranean reservoir;

determining a second predicted resource production output for the subterranean reservoir based on a sand stability model analysis for a stabilization-treated condition of the subterranean reservoir; and

outputting an economic value comparison of resource production for the native condition and resource production for the stabilization-treated condition based on the first predicted resource production output and the second predicted resource production output.

14. The computer-readable medium of claim 13, wherein the economic value comparison includes information on a net present value of resource production for the native condition and information on a net present value of resource production for the stabilization-treated condition.

15. The computer-readable medium of claim 14, the operations comprising analyzing:

calculating the net present value of resource production for the native condition based on a cost of completion under the native condition and a time value of resource production under the native condition; and

calculating the net present value of resource production for the stabilization-treated condition based on a cost of completion under the stabilization-treated condition and a time value of resource production under the stabilization-treated condition.

16. The computer-readable medium of claim 13, the operations comprising analyzing sensitivity of the economic value comparison to variations in input parameters used to determine the first predicted resource production output and the second predicted resource production output.

17. The computer-readable medium of claim 13, the operations comprising selecting a resource production plan for the subterranean reservoir based on the economic value comparison, wherein the selected resource production plan includes production of reservoir resources under the native condition or production of reservoir resources under the stabilization-treated condition.

18. The computer-readable medium of claim 13, wherein

determining the first predicted resource production output comprises:

determining a duration of wellbore productivity for the native condition based on the sand stability model analysis for the native condition; and

determining a resource production rate for the native condition over the duration of wellbore productivity for the native condition; and

determining the second predicted resource production output includes;

determining a duration of wellbore productivity for the stabilization-treated condition based on the sand stability model analysis for the stabilization-treated condition; and

determining a resource production rate for the stabilization-treated condition over the duration of wellbore productivity for the stabilization-treated condition.

19. The computer-readable medium of claim 18, wherein the duration of well bore productivity for the native condition is determined based on a predicted sand stability failure under the native condition, and the duration of well bore productivity for the stabilization-treated condition is determined based on a predicted sand stability failure under the stabilization-treated condition.

20. The computer-readable medium of claim 18, wherein the resource production rate for the native condition is determined based on a nodal analysis flow simulation for the native condition, and the resource production rate for the stabilization-treated condition is determined based on a nodal analysis flow simulation for the stabilization-treated condition.

21. A computing system comprising:

a sand stability module operable to;

model sand stability for a native condition of a subterranean reservoir; and

model sand stability for a stabilization-treated condition of the subterranean reservoir; and

a resource prediction module operable to;

determine a first predicted resource production output for the subterranean reservoir based on the sand stability model for the native condition; and

determine a second predicted resource production output for the subterranean reservoir based on the sand stability model for the stabilization-treated condition;

an economics module operable to generate an economic value comparison of resource production for the native condition and the stabilization-treated condition based on the first predicted resource production output and the second predicted resource production output.

22. The system of claim 21, wherein the resource prediction module is operable to determine wellbore duration and resource production rate based on a sand stability model.

23. The system of claim 21, wherein the economics module is operable to determine wellbore completion costs and net present value of resources.

24. The system of claim 21, wherein the sand stability module is operable to predict sand stability failure for the native condition under a mechanical sand control scheme that includes at least one of a gravel pack, a fracture pack, or sand screens.

25. The system of claim 21, wherein the sand stability module is operable to predict sand stability failure for the stabilization-treated condition based on a modeled sand consolidation treatment for the subterranean reservoir.