Methods to detect formation pressure

• US 7,266,983 B2
• Filed: 08/02/2005
• Issued: 09/11/2007
• Est. Priority Date: 09/12/2002
• Status: Expired due to Fees

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Lee, Jaedong, Krueger, Sven, Meister, Matthias, Niemeyer, Eick
• Primary Examiner(s): Williams; Hezron
• Assistant Examiner(s): BELLAMY, TAMIKO D
• Application Number:
  US11/195,310
• Publication Number:
  US 20060016594A1
• Time in Patent Office: 770 Days
• Field of Search: 731/522.1, 731/522.2, 731/522.3, 731/522, 731/525.1, 731/525.2, 731/522.7, 166/250.1, 166/264
• US Class Current: 73/152.22
• 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 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• 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

A method of determining a formation pressure during drawdown of a formation comprises sampling fluid from a formation using a downhole tool. A fluid sample pressure is determined at two different times during the drawdown. The fluid sample pressures are analyzed using a higher-order pressure derivative with respect to time technique to determine the formation pressure during the drawdown. Another method of determining a formation pressure during drawdown of a formation comprises sampling fluid from a formation using a downhole tool. A fluid sample pressure is determined at two different times during the drawdown. The fluid sample pressures are analyzed using at least two analysis techniques to each determine an estimate of the formation pressure during the drawdown.

Claims

1. A method of estimating a formation pressure during drawing of a fluid from a formation, comprising:

drawing the fluid from the formation;

determining a fluid pressure at at least two different times during the drawing of the fluid from the formation; and

analyzing the fluid pressures using a higher-order pressure

derivative with respect to time to estimate the formation pressure during the drawing of the fluid, wherein the higher-order pressure derivative with respect to time is greater than a second pressure derivative.

2. The method of claim 1, wherein the higher-order pressure derivative with respect to time comprises;

measuring a fluid pressure at a predetermined sample rate;

it calculating a higher-order pressure derivative with respect to time for each successive pressure measurement;

filtering the calculated higher-order pressure derivative with respect to time and establishing a confidence level about a substantially constant higher-order derivative with respect to time;

detecting a first peak from the substantially constant higher-order derivative with respect to time, the first peak having a value less than the substantially constant higher-order derivative with respect to time plus said confidence level and indicative of initiation of a formation test; and

detecting a second peak from the substantially constant higher-order derivative with respect to time value, the second peak having a value greater than the substantially constant value plus the confidence level and identifying the corresponding measured pressure as the formation pressure.

5. The method of claim 1 further comprising measuring each fluid pressure at a selected sample rate.

6. The method of claim 1, wherein drawing the fluid comprises drawing the fluid at a substantially constant flow rate.

7. The method of claim 1, wherein the higher-order pressure derivative with respect to time is one of (i) a third derivative, and (ii) a derivative higher than a third derivative.

8. The method of claim 1 further comprising determining the higher-order pressure derivative with respect to time for successive pressure measurements.

9. The method of claim 8, further comprising:

filtering the higher-order pressure derivative with respect to time; and

establishing a confidence level about a substantially constant higher-order pressure derivative with respect to time.

10. The method of claim 9 further comprising:

detecting a first peak from the substantially constant higher-order derivative with respect to time, the first peak having a value less than the substantially constant higher-order derivative with respect to time plus the confidence level and indicative of initiation of a formation test.

11. The method of claim 8 further comprising detecting a second peak from the substantially constant higher-order derivative with respect to time value, the second peak having a value greater than the substantially constant value plus the confidence level and identifying the corresponding measured pressure as the formation pressure.

12. The method of claim 1 further comprising controlling drawing of the fluid downhole by one of:

a controller deployed downhole; and

a controller that sends a command signal to a controller downhole.

3. A method of estimating a formation pressure during drawing of a fluid from a formation, comprising:

sampling fluid from a formation using a downhole tool;

determining a fluid sample pressure at two different times during the drawdown; and

analyzing the fluid sample pressures using at least two analysis techniques to each estimate a separate formation pressure during the drawdown, wherein the at least two analysis techniques are drawn from the group consisting of;

a first pressure derivative technique;

a higher-order pressure derivative technique;

a formation rate analysis technique;

a dp/dt-ratio technique; and

a stepwise drawdown technique.

4. The method of claim 3, wherein each of the separate formation pressure estimates is processed using a set of decision rules to provide the estimate of the formation pressure.

13. A method of testing fluid samples downhole, comprising:

lowering a tool in a wellbore, the tool having a device to withdraw the fluid samples from a formation downhole, a pressure sensor for measuring pressure of the withdrawn fluid and a controller for controlling operation of the tool;

drawing fluid samples from a formation downhole;

measuring a fluid pressure at least two different times during the withdrawal of the fluid samples; and

analyzing the fluid pressures using a higher-order pressure derivative with respect to time to determine the formation pressure during the withdrawal of the fluid samples, wherein the higher-order pressure derivative is greater than the second pressure derivative.

14. A tool for use in a wellbore, comprising:

a device adapted to drawdown fluid from a formation adjacent a wellbore;

a pressure sensor that measures pressure of the fluid; and

a controller that determines fluid pressure at at least two different times during drawing of the fluid and analyzes the fluid pressures using a higher-order pressure derivative with respect to time to estimate the formation pressure wherein the higher-order pressure derivative is greater than the second pressure derivative.

15. The tool of claim 14, wherein the device draws the fluid at a selected flow rate.

16. The tool of claim 15, wherein the device draws the fluid at a substantially constant flow rate.

17. The tool of claim 14, wherein the higher-order pressure derivative with respect to time is one of:

(i) a third derivative; and

(ii) a derivative higher than a third derivative.

18. The tool of claim 14, wherein the controller further determines the higher-order pressure derivative with respect to time for successive fluid samples.

19. The tool of claim 18, wherein the controller:

filters the higher-order pressure derivative with respect to time and establishes a substantially constant higher-order pressure derivative with respect to time.

20. The tool of claim 19 wherein the controller further detects a first peak from the substantially constant higher-order derivative with respect to time, the first peak having a value less than the substantially constant higher-order derivative with respect to time plus the confidence level and indicative of initiation of a formation test.

21. The tool of claim 20, wherein the controller further detects a second peak from said substantially constant higher-order derivative with respect to time value, the second peak having a value greater than said substantially constant value plus said confidence level and identifying the corresponding measured pressure as the formation pressure.

22. The tool of claim 14, wherein the controller is at least in part positioned at one of:

(i) downhole;

(ii) a surface location; and

(iii) at least in part downhole.

23. The tool of claim 14, wherein the controller controls an operation of the tool in response to a signal received from the surface.