Method for enhancing production allocation in an integrated reservoir and surface flow system

• US 7,379,853 B2
• Filed: 04/19/2002
• Issued: 05/27/2008
• Est. Priority Date: 04/24/2001
• Status: Active Grant

• Current Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Original Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Inventors: Middya, Usuf
• Primary Examiner(s): FREJD, RUSSELL WARREN
• Application Number:
  US10/126,215
• Publication Number:
  US 20020165671A1
• Time in Patent Office: 2,230 Days
• Field of Search: 703/2, 703/10, 702/6, 702/9, 702/12, 702/13, 166/245, 700/28
• US Class Current: 703/10
• 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 43/14 Obtaining from a multiple-zone well

Abstract

A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities is disclosed. The method includes modeling fluid flow characteristics of the wellbores and reservoirs penetrated by the wellbores. The method includes modeling fluid flow characteristics of the surface facilities. An optimizer adapted to determine an enhanced value of an objective function corresponding to the modeled fluid flow characteristics of the wellbores and the surface facilities is then operated. The objective function relates to at least one production system performance parameter. Fluid flow rates are then allocated according to the optimization.

Claims

1. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter comprising maximum oil production rate; and

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer.

2. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter comprising maximum ultimate recovery; and

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer.

3. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the objective function is optimized by successive quadratic programming; and

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer.

4. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter;

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer;

determining non-convergence of the objective function;

adjusting at least one constraint on the objective function;

recalculating the objective function; and

repeating the adjusting at least one constraint and recalculating until the objective function converges.

5. The method as defined in claim 4 further comprising:

repeating the determining non-convergence of the objective function;

adjusting at least one element of the surface facilities;

recalculating the objective function; and

repeating the adjusting at least one element and recalculating the objective function until the objective function converges.

6. The method as defined in claim 4 wherein the at least one constraint comprises maximum water production rate.

7. The method as defined in claim 4 wherein the at least one constraint comprises maximum gas/oil ratio.

8. The method as defined in claim 4 wherein the at least one constraint comprises maximum water cut.

9. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter;

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer;

calculating a fluid pressure distribution in the at least one reservoir after a selected time interval;

recalculating fluid flow rates from the wellbores in response to the fluid pressure distribution calculation; and

repeating the operating the optimizer and reallocating fluid flow rates among the wellbores in response to the repeated operating the optimizer.

10. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter; and

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer;

determining a sensitivity of the objective function to at least one system constraint;

adjusting the at least one constraint and recalculating the objective function using the adjusted constraint; and

reallocating fluid flow rates among the plurality of wellbores as determined by the recalculated objective function.

11. The method as defined in claim 10 wherein determining the sensitivity comprises determining an optimal value of the objective function by sequential quadratic approximating, and determining a value of a Lagrange multiplier associated with the at least one constraint.

12. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer to determine an enhanced value of an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the optimizer comprises at least one constraint corresponding to a target value of at least one system parameter, the optimizer reaching convergence when a value of the at least one constraint is within a range bounded by the target value; and

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer.

13. The method as defined in claim 12 wherein the at least one system parameter comprises a minimum oil production rate.

14. The method as defined in claim 12 wherein the at least one system parameter comprises a maximum water production rate.

15. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

operating an optimizer adapted to determine an optimal value of an objective function, the objective function corresponding to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, the optimizing comprising at least one constraint corresponding to a target value of at least one system operating parameter, the optimizer reaching convergence when a value of the at least one constraint is within a range bounded by the target value; and

allocating fluid flow rates among the plurality of wellbores as determined by operating the optimizer.

16. The method as defined in claim 15 wherein the at least one production system performance parameter comprises economic value.

17. The method as defined in claim 15 wherein the at least one production system performance parameter comprises water production rate.

18. The method as defined in claim 15 wherein the at least one production system performance parameter comprises minimum gas/oil ratio.

19. The method as defined in claim 15 wherein the at least one production system performance parameter comprises oil production rate.

20. The method as defined in claim 15 wherein the at least one production system performance parameter comprises ultimate recovery.

21. The method as defined in claim 15 wherein the optimizer comprises successive quadratic programming.

22. The method as defined in claim 15 further comprising:

determining non-convergence of the objective function;

adjusting the value of the at least one constraint;

recalculating the objective function; and

repeating the adjusting the value of the at least one constraint and recalculating until the objective function converges.

23. The method as defined in claim 22 further comprising:

repeating the determining non-convergence of the objective function;

adjusting at least one element of the surface facilities;

recalculating the objective function;

repeating the adjusting at least one element and recalculating until the objective function converges.

24. The method as defined in claim 22 wherein the at least one constraint comprises a maximum water production.

25. The method as defined in claim 22 wherein the at least one constraint comprises a maximum gas/oil ratio.

26. The method as defined in claim 22 wherein the at least one constraint comprises a maximum water cut.

27. The method as defined in claim 15 further comprising:

calculating a fluid pressure distribution in the at least one reservoir after a selected time interval;

recalculating fluid flow rates from the wellbores in response to the fluid pressure distribution calculation;

repeating the operating the optimizer; and

reallocating fluid flow among the plurality of wellbores in response to the repeated operation of the optimizer.

28. The method as defined in claim 15, further comprising:

determining a sensitivity of the objective function to at least one system operating constraint in a plurality of system operating constraints;

adjusting the at least one system operating constraint and recalculating the objective function using the adjusted system operating constraint; and

reallocating fluid flow rates among the plurality of wellbores as determined by the recalculated objective function.

29. The method as defined in claim 28 wherein determining the sensitivity comprises calculating the objective function by sequential quadratic approximating, and determining a value of a Lagrange multiplier associated with the at least one system operating constraint.

30. The method as defined in claim 28 wherein the at least one system operating constraint comprises a maximum water production.

31. The method as defined in claim 28 wherein the at least one system operating constraint comprises a maximum gas/oil ratio.

32. The method as defined in claim 28 wherein the at least one system operating constraint comprises a maximum water cut.

33. A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter comprises oil production rate; and

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing.

34. A method for optimizing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter comprises ultimate recovery; and

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing.

35. A method for optimizing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter, wherein the objective function is optimized by successive quadratic programming;

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing.

36. A method for optimizing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter; and

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing;

determining non-convergence of the objective function;

adjusting at least one constraint on the objective function;

recalculating the objective function; and

repeating the adjusting at least one constraint and recalculating until the objective function converges.

37. The method as defined in claim 36 further comprising:

repeating the determining non-convergence of the objective function;

adjusting at least one element of the surface facilities;

recalculating the objective function; and

repeating the adjusting at least one element and recalculating until the objective function converges.

38. The method as defined in claim 36 wherein the at least one constraint comprises water production rate.

39. The method as defined in claim 36 wherein the at least one constraint comprises gas/oil ratio.

40. The method as defined in claim 36 wherein the at least one constraint comprises water cut.

41. A method for optimizing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter; and

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing;

calculating a fluid pressure distribution in the at least one reservoir after a selected time interval;

recalculating fluid flow rates from the wellbores in response to the fluid pressure distribution calculation;

repeating the optimizing the objective function; and

reallocating fluid flow among the plurality of wellbores in response to the repeated optimizing.

42. A method for optimizing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter;

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing;

determining a sensitivity of the objective function to at least one system constraint;

adjusting the at least one constraint and recalculating the objective function using the adjusted constraint; and

reallocating fluid flow rates among the plurality of wellbores as determined by the recalculated objective function.

43. The method as defined in claim 42 wherein determining the sensitivity comprises optimizing the objective function by sequential quadratic approximating, and determining a value of a Lagrange multiplier associated with the at least one constraint.

44. A method for optimizing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding simultaneously to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter, wherein the at least one production system performance parameter, wherein the optimizing comprises at least one constraint corresponding to a target value of at least one system parameter, the optimizing adapted to converge when a value of the at least one constraint is within a range bounded by the target value.

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing;

45. The method as defined in claim 44 wherein the at least one system parameter comprises a minimum oil production rate.

46. The method as defined in claim 44 wherein the at least one system parameter comprises a maximum water production rate.

47. A method for optimizing allocation of fluid flow among a plurality of wellbores coupled to surface facilities, comprising:

modeling fluid flow characteristics of the wellbores and at least one reservoir penetrated thereby;

modeling fluid flow characteristics of the surface facilities;

optimizing an objective function, the objective function corresponding to the modeled fluid flow characteristics of the wellbores and the surface facilities, the objective function relating to at least one production system performance parameter;

determining a sensitivity of the objective function to at least one system constraint;

adjusting the at least one system constraint and recalculating the objective function using the adjusted system constraint; and

reallocating fluid flow rates among the plurality of wellbores as determined by the recalculated objective function; and

allocating fluid flow rates among the plurality of wellbores as determined by the optimizing.

48. The method as defined in claim 47 wherein the at least one production system performance parameter comprises economic value.

49. The method as defined in claim 47 wherein the at least one production system performance parameter comprises water production rate.

50. The method as defined in claim 47 wherein the at least one production system performance parameter comprises gas/oil ratio.

51. The method as defined in claim 47 wherein the at least one production system performance parameter comprises oil production rate.

52. The method as defined in claim 47 wherein the at least one production system performance parameter comprises ultimate recovery.

53. The method as defined in claim 47 wherein the objective function is optimized by successive quadratic programming.

54. The method as defined in claim 47 further comprising:

determining non-convergence of the objective function;

adjusting at least one constraint on the objective function;

recalculating the objective function; and

repeating the adjusting at least one constraint and recalculating until the objective function converges.

55. The method as defined in claim 54 further comprising:

repeating the determining non-convergence of the objective function;

adjusting at least one element of the surface facilities;

recalculating the objective function;

repeating the adjusting at least one element and recalculating until the objective function converges.

56. The method as defined in claim 54 wherein the at least one constraint comprises water production rate.

57. The method as defined in claim 54 wherein the at least one constraint comprises gas/oil ratio.

58. The method as defined in claim 54 wherein the at least one constraint comprises water cut.

59. The method as defined in claim 47 further comprising:

calculating a fluid pressure distribution in the at least one reservoir after a selected time interval;

recalculating fluid flow rates from the wellbores in response to the fluid pressure distribution calculation;

repeating the optimizing the objective function; and

reallocating fluid flow among the plurality of wellbores in response to the repeated optimizing.

60. The method as defined in claim 47 wherein determining the sensitivity comprises optimizing the objective function by sequential quadratic approximating, and determining a value of a Lagrange multiplier associated with the at least one constraint.

61. The method as defined in claim 47 wherein the optimizing comprises at least one constraint corresponding to a target value of at least one system parameter, the optimizing adapted to converge when a value of the at least one constraint corresponding to the target value is within a range bounded by the target value.

62. The method as defined in claim 61 wherein the at least one system parameter comprises an oil production rate.

63. The method as defined in claim 61 wherein the at least one system parameter comprises a water production rate.