Computational Model for Tracking Ball Sealers in a Wellbore

• US 20160130933A1
• Filed: 05/02/2014
• Published: 05/12/2016
• Est. Priority Date: 05/02/2014
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Madasu, Srinath, Lin, Avi
• Granted Patent: US 9,670,769 B2
• Time in Patent Office: Days
• US Class Current: 1/1
• CPC Class Codes: E21B 33/02 Surface sealing or packing
• CPC Class Codes: E21B 33/13 Methods or devices for cementing, for plugging holes, crevices or the like
• CPC Class Codes: E21B 33/138 Plastering the borehole wall; Injecting into the formation
• CPC Class Codes: E21B 47/09 Locating or determining the position of objects in boreholes or wells , e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
• CPC Class Codes: G06F 17/10 Complex mathematical operations function generation by table look-up G06F1/03; evaluation of elementary functions by calculation G06F7/544
• CPC Class Codes: G06F 30/20 Design optimisation, verification or simulation optimisation, verification or simulation of circuit designs G06F30/30

Abstract

In accordance with some embodiments of the present disclosure, a method of computational modeling for tracking ball scalers in a wellbore is disclosed. The method may include, for a time step, calculating a number of ball sealers to inject into a wellbore, injecting the ball sealers, determining a length of the wellbore occupied by a fluid, and computing a spacing between each ball sealer in the length of the wellbore occupied by the fluid. The method may include calculating a first position of a ball sealer, determining a velocity the ball sealer, and computing a second position of the ball sealer. The method may include recording a number of active ball sealers and open perforations in the wellbore, calculating a ball sealer skin per division, and determining a fluid flow rate. The method may include selecting parameters for a stimulation operation in the wellbore based on the fluid flow rate.

Claims

1. A method of computational modeling for tracking ball sealers in a wellbore, the method comprising:

calculating a number of ball sealers to inject into a wellbore at a time step;

injecting a plurality of ball sealers into the wellbore at a time step based on the calculated number of ball sealers to inject;

determining a length of the wellbore occupied by a fluid at the time step;

computing a spacing between each of the plurality of ball sealers in the length of the wellbore occupied by the fluid at the time step;

calculating a first position of at least one of the plurality of ball sealers;

determining a velocity of the at least one of the plurality of ball sealers;

computing a second position of the at least one of the plurality of ball sealers based on the first position of the at least one of the plurality of ball sealers and the velocity of the at least one of the plurality of ball sealers;

recording a number of active ball sealers and a number of open perforations in the wellbore based on the second position of the at least one of the plurality of ball sealers;

calculating a ball sealer skin per division for the at least one of the plurality of ball sealers based on the number of active ball sealers and the number of open perforations in the wellbore;

determining a fluid flow rate of the fluid based on the ball sealer skin per division for at least one of the plurality of ball sealers; and

selecting parameters for a stimulation operation in the wellbore based on the fluid flow rate of the fluid.

2. The method of claim 1, wherein determining a velocity of the at least one of the plurality of ball sealers includes calculating a velocity due to buoyancy based on a type of fluid injected.

3. The method of claim 1, wherein selecting parameters for a stimulation operation in the wellbore includes selecting at least one of the number of ball sealers to inject at the time step, a pumping schedule, or a size of the at least one of the plurality of ball sealers.

4. The method of claim 1, wherein selecting parameters for a stimulation operation in the wellbore is done in real-time during a stimulation operation.

5. The method of claim 1, wherein injecting the plurality of ball sealers further includes uniformly distributing the plurality of ball sealers in the fluid injected at the time step.

6. The method of claim 1, wherein the number of ball sealers injected at the time step is proportional to a volume of the fluid injected at the step time.

7. The method of claim 1, wherein calculating a number of ball sealers to inject into a wellbore further includes:

determining whether a first calculated value of the number of ball sealers to inject at a first time step is an integer; and

based on the determination that the first calculated value is not an integer;

selecting the integer portion of the first calculated value as the number of ball sealers to inject into a wellbore at the first time step;

saving the fractional portion of the first calculated value; and

during a second calculation of the number of ball sealers to inject into the wellbore at a second time step, adding the fraction portion of the first calculated value to the second calculated value of the number of ball sealers to inject into the wellbore at the second time step.

8. A non-transitory machine-readable medium comprising instructions stored therein, the instructions executable by one or more processors to facilitate performing a method of computational modeling for tracking ball sealers in a wellbore, the method comprising:

calculating a number of ball sealers to inject into a wellbore at a time step;

injecting a plurality of ball sealers into the wellbore at a time step based on the calculated number of ball sealers to inject;

determining a length of the wellbore occupied by a fluid at the time step;

computing a spacing between each of the plurality of ball scalers in the length of the wellbore occupied by the fluid at the time step;

calculating a first position of at least one of the plurality of ball sealers;

determining a velocity of the at least one of the plurality of ball sealers;

computing a second position of the at least one of the plurality of ball sealers based on the first position of the at least one of the plurality of ball sealers and the velocity of the at least one of the plurality of ball sealers;

recording a number of active ball sealers and a number of open perforations in the wellbore based on the second position of the at least one of the plurality of ball sealers;

calculating a ball sealer skin per division for the at least one of the plurality of ball sealers based on the number of active ball sealers and the number of open perforations in the wellbore;

determining a fluid flow rate of the fluid based on the ball sealer skin per division for at least one of the plurality of ball sealers; and

selecting parameters for a stimulation operation in the wellbore based on the fluid flow rate of the fluid.

9. The non-transitory machine-readable medium of claim 8, wherein determining a velocity of the at least one of the plurality of ball scalers includes calculating a velocity due to buoyancy based on a type of fluid injected.

10. The non-transitory machine-readable medium of claim 8, wherein selecting parameters for a stimulation operation in the wellbore includes selecting at least one of the number of ball sealers to inject at the time step, a pumping schedule, or a size of the at least one of the plurality of ball sealers.

11. The non-transitory machine-readable medium of claim 8, wherein selecting parameters for a stimulation operation in the wellbore is done in real-time during a stimulation operation.

12. The non-transitory machine-readable medium of claim 8, wherein injecting the plurality of ball sealers further includes uniformly distributing the plurality of ball sealers in the fluid injected at the time step.

13. The non-transitory machine-readable medium of claim 8, wherein the number of ball sealers injected at the time step is proportional to a volume of the fluid injected at the step time.

14. The non-transitory machine-readable medium of claim 8, wherein calculating a number of ball sealers to inject into a wellbore at a time step further includes:

determining whether a first calculated value of the number of ball sealers to inject at a first time step is an integer; and

based on the determination that the first calculated value is not an integer;

selecting the integer portion of the first calculated value as the number of ball sealers to inject into a wellbore at the first time step;

saving the fractional portion of the first calculated value; and

during a second calculation of the number of ball sealers to inject into the wellbore at a second time step, adding the fraction portion of the first calculated value to the second calculated value of the number of ball sealers to inject into the wellbore at the second time step.

15. A drilling system, comprising:

a wellbore, including a plurality of perforations;

a fluid inserted into the wellbore;

a plurality of ball sealer in the fluid; and

a modeling system, the modeling system configured to track ball sealers in a wellbore by;

calculating a number of ball sealers to inject into the wellbore at a time step;

injecting a plurality of ball scalers into the wellbore at a time step based on the calculated number of ball sealers to inject;

determining a length of the wellbore occupied by a fluid at the time step;

computing a spacing between each of the plurality of ball sealers in the length of the wellbore occupied by the fluid at the time step;

calculating a first position of at least one of the plurality of ball sealers;

determining a velocity of the at least one of the plurality of ball sealers;

computing a second position of the at least one of the plurality of ball sealers based on the first position of the at least one of the plurality of ball sealers and the velocity of the at least one of the plurality of ball sealers;

recording a number of active ball sealers and a number of open perforations in the wellbore based on the second position of the at least one of the plurality of ball sealers;

calculating a ball sealer skin per division for the at least one of the plurality of ball sealers based on the number of active ball sealers and the number of open perforations in the wellbore;

determining a fluid flow rate of the fluid based on the ball sealer skin per division for at least one of the plurality of ball sealers; and

selecting parameters for a stimulation operation in the wellbore based on the fluid flow rate of the fluid.

16. The drilling system of claim 15, wherein determining a velocity of the at least one of the plurality of ball sealers includes calculating a velocity due to buoyancy based on a type of fluid injected.

17. The drilling system of claim 15, wherein selecting parameters for a stimulation operation in the wellbore includes selecting at least one of the number of ball sealers to inject at the time step, a pumping schedule, or a size of the at least one of the plurality of ball sealers.

18. The drilling system of claim 15, wherein selecting parameters for a stimulation operation in the wellbore is done in real-time during a stimulation operation.

19. The drilling system of claim 15, wherein injecting the plurality of ball sealers further includes uniformly distributing the plurality of ball sealers in the fluid injected at the time step.

20. The drilling system of claim 15, wherein the number of ball sealers injected at the time step is proportional to a volume of the fluid injected at the step time.