Method and apparatus for sampling formation fluids

• US 7,703,317 B2
• Filed: 09/07/2007
• Issued: 04/27/2010
• Est. Priority Date: 09/18/2006
• Status: Expired due to Fees

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Goodwin, Anthony R. H., Hegeman, Peter S.
• Primary Examiner(s): FITZGERALD, JOHN P
• Application Number:
  US11/851,584
• Publication Number:
  US 20080066536A1
• Time in Patent Office: 963 Days
• Field of Search: 731/520.5, 731/520.7, 731/521.1, 731/521.2, 731/521.3, 731/521.7, 731/523.9, 731/524.1, 731/522.4, 166/100, 166/166, 166/264, 166/272.1, 166/400
• US Class Current: 73/152.24
• CPC Class Codes: E21B 49/10 using side-wall fluid samplers or testers

Abstract

A method of retrieving a formation fluid from a formation adjacent a borehole wall includes estimating at least one of a permeability of the formation and a viscosity of the formation fluid. A first tool is selected based on the estimation, the first tool being selected from one of a heating and sampling tool, an injection and sampling tool, and a coring tool. An attempt to retrieve a formation fluid sample from the formation is then made with the first tool, and a formation fluid sample is retrieved from the formation. A second retrieval process may then be initiated, in which the second retrieval process includes increasing the mobility of the formation fluid.

Claims

1. A method of retrieving a formation fluid from a formation adjacent a borehole wall, comprising:

estimating at least one of a permeability of the formation, a viscosity of the formation fluid, and a mobility of the formation fluid;

selecting a first tool based on the estimation, the first tool being selected from one of a heating and sampling tool, an injection and sampling tool, and a coring tool;

attempting to retrieve a formation fluid sample from the formation with the first tool;

selecting a second tool after attempting to retrieve a formation fluid sample; and

retrieving a formation fluid sample from the formation with the second tool.

2. The method of claim 1 wherein estimating includes estimating a mobility range of the formation fluid.

3. The method of claim 1 wherein the estimation is based on at least one of a current well log, formation data of another well, a log of another well, formation data of the current well, a cutting analysis of the current well, a cutting analysis of another well, or a reservoir model.

4. The method of claim 1 further comprising selecting a configuration for the first tool, the configuration being selected from one of a single probe configuration, a multi probe configuration, an inflatable multi-packer configuration, and a guard probe configuration.

5. The method of claim 1 wherein the first tool includes at least one of an inflatable packer and a probe, and the method further comprises selecting a dimension related to the at least one of an inflatable packer and a probe.

6. The method of claim 1 wherein selecting the first tool is accomplished while the tool is downhole.

7. The method of claim 1 wherein selecting the second tool is based on data collected during the formation fluid sample retrieval attempted with the first tool.

8. The method of claim 7 wherein the collected data includes at least one of mobility data, pressure data, temperature data, viscosity data, flowrate data, permeability data, density data and composition data.

9. The method of claim 1 further comprising selecting at least one operating parameter for a component of the first tool.

10. The method of claim 9 wherein the first tool comprises a pump, and selecting at least one operating parameter comprises selecting at least one of a pumping flowrate and a pumping pressure differential.

11. The method of claim 9 wherein selecting the first tool comprises selecting an injection and sampling tool that comprises an injection mechanism, and wherein selecting the at least one operating parameter comprises selecting at least one of an injection rate, an injection volume, an injection medium and an injection ratio.

12. The method of claim 9 wherein selecting the first tool comprises selecting a heating and sampling tool that comprises at least one of a heating mechanism at least partially extendable from the first tool, a heating mechanism disposed at least partially in the first tool, and a heating mechanism disposed at least partially adjacent the tool, and wherein selecting the at least one operating parameter includes selecting at least one of an amount of heat emanating from the heating mechanism, an amount of energy provided to the heating mechanism, and a distance the heating mechanism extends into the formation.

13. A method of retrieving a formation fluid from a formation adjacent a borehole wall, comprising:

estimating at least one of a permeability of the formation, a viscosity of the formation fluid, and a mobility of the formation fluid;

selecting a first tool based on the estimation, the first tool being selected from one of a heating and sampling tool, an injection and sampling tool, and a coring tool;

attempting to retrieve a formation fluid sample from the formation with the first tool; and

retrieving a formation fluid sample from the formation;

wherein attempting to retrieve the formation fluid sample comprises;

initiating a first retrieval process comprising attempting to increase the mobility of the formation fluid;

measuring at least one downhole parameter related to the mobility of the fluid;

changing the first retrieval process to a second retrieval process based on the measured downhole parameter; and

initiating a second retrieval process comprising increasing the mobility of the formation fluid; and

wherein retrieving the formation fluid sample from the formation comprises completing the second retrieval process.

14. The method of claim 13 wherein measuring at least one downhole parameter comprises measuring at least one of a mobility of the formation fluid, a pressure of the formation fluid, a temperature, a viscosity of the formation fluid, a flowrate, and a permeability of the formation.

15. The method of claim 13 wherein initiating the first retrieval process, measuring at least one downhole parameter, changing the first retrieval process, and initiating the second retrieval process are all accomplished while the first tool is downhole.

16. The method of claim 13 wherein the first tool comprises at least one sensor, a processor, and a controller communicably coupled to one another, and wherein changing the first retrieval process comprises:

processing data obtained by the sensor with the processor; and

at least partially changing the first retrieval process with the controller.

17. The method of claim 13 wherein one of the first and the second retrieval processes comprises initiating a coring process, removing a core from the formation, and placing the core into the first tool, and wherein retrieving formation fluid comprises retrieving formation fluid from the core.

18. The method of claim 17 wherein retrieving formation fluid from the core is accomplished at the surface.

19. The method of claim 17 wherein retrieving formation fluid from the core is accomplished within the wellbore.

20. The method of claim 13 wherein initiating the first retrieval process comprises at least one of mixing a plurality of fluids to be injected into the formation, injecting fluid into the formation, energizing an RF heating element, energizing a resistive heating element, energizing an ultra-sonic heating element, and energizing a conductive heating element.

21. The method of claim 20 wherein the first tool comprises a pump, and wherein changing the first retrieval process comprises changing at least one of a pumping flowrate and a pumping pressure differential.

22. The method of claim 20 wherein the first tool comprises an injection mechanism, and wherein changing the first retrieval process comprises changing at least one of a fluid mixing ratio, an amount of fluid injected into the formation, a temperature of the fluid injected into the formation, a flowrate of the fluid injection into the formation, and an injection medium.

23. The method of claim 20 wherein the first tool comprises at least one of a heating mechanism at least partially extendable from the first tool, a heating mechanism disposed at least partially in the first tool, and a heating mechanism disposed at least partially adjacent the first tool, and wherein changing the first retrieval process comprises changing at least one of an amount of heat emanating from the heating mechanism, an amount of energy provided to the heating mechanism, and a distance the heating mechanism extends into the formation.

24. The method of claim 20 wherein the first tool includes at least one of a plurality of inflatable packers and at least one probe, and wherein changing the first retrieval process comprises changing at least one of a probe-related dimension and a packer-related spacing.

25. A method, comprising:

positioning a downhole tool in a wellbore extending through a subterranean formation,

wherein the downhole tool comprises a first tool and a second tool;

attempting unsuccessfully to retrieve a formation fluid sample from the formation with the first tool; and

retrieving a formation fluid sample from the formation with the second tool;

wherein the first tool is one selected from the group consisting of a heating and sampling tool, an injection and sampling tool, and a coring tool, and wherein the second tool is a different one selected from the group.