Method and apparatus for pumping quality control through formation rate analysis techniques

• US 7,234,521 B2
• Filed: 03/10/2004
• Issued: 06/26/2007
• Est. Priority Date: 03/10/2003
• Status: Expired due to Term

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Lee, Jaedong, Shammai, Michael
• Primary Examiner(s): THOMPSON, KENNETH L
• Application Number:
  US10/797,815
• Publication Number:
  US 20040231842A1
• Time in Patent Office: 1,203 Days
• Field of Search: 166/264, 166/66, 166/250.02, 166/250.07, 166/250.17, 166/100, 731/521.8, 731/522.3, 731/522.4
• US Class Current: 166/264
• CPC Class Codes: E21B 49/008 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 Class Codes: E21B 49/081 with down-hole means for trapping a fluid sample E21B49/10 takes precedence
• CPC Class Codes: E21B 49/10 using side-wall fluid samplers or testers

Abstract

The present invention provides a method and apparatus for determination of the quality of a formation fluid sample including monitoring permeability and mobililty versus time to determine a filtrate contamination level, single phase state without gas and solids in the formation fluid, as it existed in the formation and the determination of laminar flow from the formation. The present invention also enables determination of an optimal pumping rate to match the ability of a subsurface formation to produce a single phase formation fluid sample in minimum time. The method and apparatus also detect pumping problems such as sanding and loss of seal with borehole.

Claims

1. A method for estimating a flow rate of a fluid from a formation, comprising:

pumping to remove the fluid from the formation;

measuring fluid pressure during pumping;

tracking a volume pumped during pumping;

estimating a fluid property comprising at least one of the set consisting of permeability, mobility and compressibility for the fluid from the flow rate;

optimizing a fluid pumping rate based the property to acquire the fluid substantially in a single-phase; and

estimating the flow rate of the fluid from the measured pressure and volume.

2. The method of claim 1, wherein tracking volume comprises tracking a position of a pumping piston.

3. The method of claim 1, wherein the measuring the fluid pressure further comprises measuring pressure in a flow line for the fluid.

4. The method of claim 1 further comprising:

detecting a pumping problem if the property is outside a predetermined limit.

5. The method of claim 1, further comprising estimating a quality of the fluid from the property over time.

6. The method of claim 1, further comprising:

determining a correlation coefficient for estimates of the property; and

detecting a pumping problem based on the correlation coefficient.

7. A method for estimating a flow rate of a fluid from a formation, comprising:

pumping to remove the fluid from the formation;

measuring fluid pressure during pumping;

tracking a volume pumped during pumping;

estimating a fluid property comprising at least one of the set consisting of permeability, mobility and compressibility for the fluid from the flow rate;

estimating the flow rate of the fluid from the measured pressure and volume;

monitoring the fluid property versus time to determine formation cleanup.

8. A method for estimating a

flow rate of a fluid from a formation, comprising:

pumping to remove the fluid from the formation;

measuring fluid pressure during pumping;

tracking a volume pumped during pumping;

estimating the flow rate of the fluid from the measured pressure and volume; and

monitoring the flow rate versus time to determine whether a formation fluid sample is in a single phase state.

9. A method for determining success of a pumping operation comprising:

estimating flow rate and pressure for a fluid pumped from a formation; and

estimating a correlation between the flow rate and pressure; and

estimating the success of the pumping operation based on the correlation,

wherein success of the pumping operation further comprises a limited pressure drop in a sample acquired.

10. The method of claim 9 further comprising:

maximizing a pumping rate based on the correlation, to acquire the fluid in a single-phase.

11. An apparatus for retrieving fluid comprising:

a pump whose volume can be tracked that retrieves the fluid from a formation;

a pressure gauge that measures pressure of the fluid; and

a processor programmed to track success of retrieving the fluid from volume and pressure, wherein the processor is programmed to estimate a fluid property selected from a group consisting of permeability, mobility and compressibility, wherein the pump removes the fluid at a rate based on the property to acquire the fluid substantially in a single-phase.

12. The apparatus of claim 11, where processor changes speed of pumping to optimize retrieval.

13. The apparatus of claim 11, further comprising:

a tank for holding the fluid.

14. The apparatus of claim 11 wherein the processor is programmed to provide an indicator to maximize the pumping rate based on the property, to acquire the fluid in a single-phase.

15. The apparatus of claim 11, wherein the pump removes the fluid from the formation and pumps the fluid into a sample chamber through a flow line.

16. The apparatus of claim 11, wherein the pressure gauge measures fluid pressure in the flow line.

17. The apparatus of claim 11, wherein the processor detects a pumping problem if the property is outside a predetermined limit.

18. An apparatus for retrieving fluid comprising:

a pump whose volume can be tracked that retrieves the fluid from a formation;

a pressure gauge that measures pressure of the fluid; and

a processor programmed to track success of retrieving the fluid from volume and pressure, wherein the processor is programmed to estimate a fluid property selected from a group consisting of permeability, mobility and compressibility, wherein the processor is further programmed to one of;

(i) estimate a quality of the fluid from the property measured over time, (ii) estimate a correlation coefficient for estimates of the property and detect a pumping problem based on the correlation coefficient, (iii) monitor the property versus time to determine formation cleanup, and (iv) monitor the property versus time and estimate whether the fluid sample is in a single phase state.

19. A system for estimating a property of a fluid, comprising:

a down hole tool;

a pump in the downhole tool that removes the fluid from a formation, wherein the pump removes the fluid at a rate based on the property to acquire the fluid substantially in a single-phase;

a pump position indicator;

a pressure gauge that measures fluid pressure corresponding to a pump piston position indicated by the pump position indicator; and

a processor that estimates the property of the fluid from the measured pressure and pump position.

20. The downhole tool of claim 19, wherein the property is selected from a group consisting of permeability, mobility and compressibility.

21. The downhole tool of claim 19 wherein the processor provides an indicator to maximize the pumping rate based on the property, to acquire the fluid in a single-phase.

22. The downhole tool of claim 19, wherein the pump removes the fluid from the formation and pumps the fluid into a sample chamber through a flow line.

23. The downhole tool of claim 22, wherein the pressure gauge measures fluid pressure in the flow line.

24. The downhole tool of claim 19, wherein the processor detects a pumping problem if the property is outside a predetermined limit.

25. The downhole tool of claim 19, wherein the processor is programmed to estimate a quality of the fluid from the property measured over time.

26. The downhole tool of claim 19, wherein the processor is programmed to estimate a correlation coefficient for estimates of the property and detect a pumping problem based on the correlation coefficient.

27. The downhole tool of claim 19, wherein the processor is programmed to monitor the property versus time to estimate formation cleanup.

28. The downhole tool of claim 19, wherein the processor monitors the property versus time to estimate whether the fluid is in a single phase state.