Method for measuring formation properties with a time-limited formation test

• US 6,832,515 B2
• Filed: 09/09/2002
• Issued: 12/21/2004
• Est. Priority Date: 09/09/2002
• Status: Expired due to Term

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Follini, Jean-Marc, Pop, Julian
• Primary Examiner(s): Bagnell, David
• Assistant Examiner(s): BOMAR, THOMAS S
• Application Number:
  US10/237,394
• Publication Number:
  US 20040050588A1
• Time in Patent Office: 834 Days
• Field of Search: 731/520.2, 731/520.5, 731/521.8, 731/522.8, 731/525.2, 166/264, 166/100, 166/64, 166/65.1, 166/244.1, 166/250.01, 166/250.07, 166/250.17, 175/50, 175/64, 175/65.1, 175/244.1, 175/250.01, 175/250.07, 175/250.17
• US Class Current: 73/152.02
• CPC Class Codes: E21B 49/00 Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• 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 49/10 using side-wall fluid samplers or testers

Abstract

An apparatus and method for determining at least one downhole formation property is disclosed. The apparatus includes a probe and a pretest piston positionable in fluid communication with the formation, and a series of flowlines pressure gauges, and valves configured to selectively draw into the apparatus for measurement of one of formation fluid and mud. The method includes performing a first pretest to determine an estimated formation parameter; using the first pretest to design a second pretest and generate refined formation parameters whereby formation properties may be estimated.

Claims

1. A method for determining at least one formation fluid property using a formation tester, comprising:

collecting a first set of data points representing pressures in a pretest chamber of the formation tester as a function of time during a first pretest;

determining a set of parameters for a second pretest, the set of parameters being determined based on estimated formation properties derived from the first set of data points and a time remaining for performing the second pretest;

performing the second pretest using the set of parameters;

collecting a second set of data points representing pressures in the pretest chamber as a function of time during the second pretest; and

determining the at least one formation fluid property from the second set of data points.

2. The method of claim 1, wherein the estimated formation properties comprise an estimated formation pressure and an estimated formation fluid mobility.

3. The method of claim 1, wherein the at least one formation fluid property comprises one selected from the group consisting of formation pressure and formation fluid mobility.

4. The method of claim 1, wherein the set of parameters comprise at least one selected from the group consisting of a drawdown volume for the second pretest, a flow rate for a drawdown phase in the second pretest, a duration for the drawdown phase in the second pretest, a duration for a buildup phase in the second pretest, and a criterion for terminating the drawdown phase in the second pretest.

5. The method of claim 1, further comprising determining a mud compressibility before the collecting the first set of data points.

6. The method of claim 5, wherein the determining the mud compressibility comprises:

isolating a volume of a drilling fluid in a flow line that is in fluid communication with the pretest chamber of the formation tester;

collecting a set of data points representing pressures in the pretest chamber as a function of time while moving a piston in the pretest chamber; and

determining the mud compressibility from the set of data points.

7. The method of claim 5, wherein the mud compressibility is used to determine a condition for terminating a drawdown phase in the first pretest.

8. The method of claim 7, wherein the condition for terminating the drawdown phase is based on finding a straight line having a fixed slope, the straight line representing a flow line expansion in the drawdown phase.

9. The method of claim 8, wherein the fixed slope is determined by the mud compressibility, a flow line volume, and the piston drawdown rate.

10. The method of claim 8, wherein the finding the straight line is performed by finding a series of consecutive data points in the drawdown phase having substantially identical intercepts on a pressure versus time plot when each of the data points is fitted to a line with the fixed slope.

11. The method of claim 8, wherein the finding the straight line is performed by finding a series of consecutive data points in the drawdown phase having substantially identical variances when each of the data points is fitted to the straight line with the fixed slope.

12. The method of claim 5, further comprising determining a mud filtration rate after the determining the mud compressibility.

13. The method of claim 12, wherein the finding the mud filtration rate comprises:

isolating a volume of the drilling fluid in a flow line that is in fluid communication with the pretest chamber and a formation;

compressing the volume of the drilling fluid with the piston;

collecting data points representing pressures in the pretest chamber as a function of time after the compressing is terminated; and

determining the mud filtration rate from the data points.

14. The method of claim 12, wherein the mud filtration rate is used to determine a condition for terminating a drawdown phase in the first pretest.

15. A method for determining at least one formation fluid property using a formation tester in a formation penetrated by a borehole, comprising:

collecting a first set of data points representing pressures in a pretest chamber of the formation tester as a function of time during a first pretest;

determining an estimated formation pressure and an estimated formation fluid mobility from the first set of data points;

determining a set of parameters for a second pretest, the set of parameters being determined based on the estimated formation pressure, the estimated formation fluid mobility, and a time remaining for performing the second pretest;

performing the second pretest using the set of parameters;

collecting a second set of data points representing pressures in the pretest chamber as a function of time during the second pretest; and

determining the at least one formation fluid property from the second set of data points.

16. The method of claim 15, wherein the at least one formation property comprises at least one selected from the group consisting of a formation pressure and a formation fluid mobility.

17. The method of claim 16, wherein the set of parameters for the second pretest comprise at least one selected from the group consisting of a pretest piston drawdown rate, a drawdown volume, a maximum drawdown pressure drop, and a duration for a buildup phase.

18. The method of claim 17, wherein a drawdown phase in the first pretest is terminated based on a criterion relative to a first data point past a stretch of data points representing a linear flowline expansion pressure trend, wherein the linear flowline expansion pressure trend is found by fitting data points to a line with a fixed slope, the first data point past the stretch deviates from the line with the fixed slope by a deviation greater than a predetermined value.

19. The method of claim 18, wherein the criterion is one selected from a group consisting of a pressure drop, a withdrawn volume, and a duration.

20. The method of claim 19, wherein a buildup phase of the first pretest is terminated based on a ratio of a duration of the drawdown phase and a duration of the buildup phase.

21. The method of claim 20, wherein the first estimated formation pressure is determined from a last data point from the buildup phase of the first pretest.