Use of distributed temperature sensors during wellbore treatments

• US 7,055,604 B2
• Filed: 07/28/2003
• Issued: 06/06/2006
• Est. Priority Date: 08/15/2002
• Status: Expired due to Term

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Gay, Michael, Adnan, Sarmad, Thomeer, Hubertus, Flamant, Nicolas, Jee, Virginia
• Primary Examiner(s): Bagnell, David
• Assistant Examiner(s): WRIGHT, GIOVANNA COLLINS
• Application Number:
  US10/604,515
• Publication Number:
  US 20040129418A1
• Time in Patent Office: 1,044 Days
• Field of Search: 166/305.1, 166/312, 166/250.01, 731/521.1, 731/521.8, 731/525.5
• US Class Current: 166/305.1
• CPC Class Codes: C12N 13/00 Treatment of microorganisms or enzymes with electrical or wave energy, e.g. magnetism, sonic waves
• CPC Class Codes: C12N 15/02 Preparation of hybrid cells by fusion of two or more cells, e.g. protoplast fusion monoclonal antibodies C07K16/00; apparatus for cell fusion C12M
• CPC Class Codes: E21B 43/27 by use of eroding chemicals, e.g. acids
• CPC Class Codes: E21B 47/07 Temperature
• CPC Class Codes: E21B 47/13 by electromagnetic energy, e.g. radio frequency
• CPC Class Codes: G01D 5/35383 using multiple sensor devices using multiplexing techniques
• CPC Class Codes: G01K 11/32 using changes in transmittance, scattering or luminescence in optical fibres
• CPC Class Codes: G16B 25/00 ICT specially adapted for hybridisation; ICT specially adapted for gene or protein expression
• CPC Class Codes: G16B 40/00 ICT specially adapted for biostatistics; ICT specially adapted for bioinformatics-related machine learning or data mining, e.g. knowledge discovery or pattern finding
• CPC Class Codes: H04L 65/1101 Session protocols

Abstract

The invention relates to a method for treating subterranean formation comprising providing distributed temperature sensors, injecting a treatment fluid and monitoring the temperature across the treatment interval during the injection process.

Claims

1. A method for treating a drilled well, the method comprising the steps of:

positioning distributed temperature sensors on a fiber along an interval within a well, wherein the distributed temperature sensors provide substantially continuous temperature monitoring along the interval;

obtaining a baseline temperature profile across the interval;

monitoring substantially continuously the temperature along the interval;

calculating a differential temperature profile across the interval relative to the baseline temperature profile;

injecting a fluid into the well and into one or more zones surrounding the interval;

shutting-in the well until the temperature in the well substantially stabilizes;

monitoring the shut-in temperature along the interval during the shut-in period;

determining the shut-in temperature deviation relative to the baseline temperature profile across the interval; and

determining the one or more formation zones in which the injected fluid flowed.

2. The method of claim 1, further comprising the step of determining the shut-in temperature deviation relative to the differential temperature profile measured prior to the shut-in.

3. The method of claim 1, further comprising the step of determining the volume of the fluid injected into the one or more zones.

4. The method of claim 1, wherein the fiber has a bottom end including a temperature sensor for substantially continuous monitoring of bottom-hole temperature.

5. The method of claim 1, wherein the fiber has a bottom end, the bottom end including a temperature sensor for substantially continuous monitoring of bottom-hole temperature and a pressure sensor for measuring for substantially continuous monitoring of bottom-hole pressure.

6. The method of claim 1, wherein the fiber has a bottom end including a pressure sensor for substantially continuous monitoring of bottom-hole pressure.

7. The method of claim 1, further including the step of injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.

8. The method of claim 1, further including the steps of:

injecting a diverter into the well pursuant to the step of determining the zone of injection of the prior injected fluid; and

injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.

9. The method of claim 1, wherein the fluid is a matrix treatment agent.

10. The method of claim 1, wherein the fluid is a matrix acidizing agent.

11. The method of claim 1, wherein the fluid is a fracturing agent.

12. The method of claim 1, wherein the fluid is an acid fracturing agent.

13. The method of claim 1, wherein the fluid is a gravel packing agent.

14. A method for treating a drilled well, the method comprising the steps of:

positioning distributed temperature sensors on a fiber along an interval within a well surrounded by one or more formation zones, wherein the distributed temperature sensors provide substantially continuously temperature monitoring along the interval;

obtaining a baseline temperature profile across the interval;

monitoring substantially continuously the temperature along the interval;

calculating a differential temperature profile across the interval relative to the baseline temperature profile;

injecting a fluid non-reactive with the one or more formation zones into the well and the one or more formation zones;

calculating the injectivity of the one or more formation zones based on temperature profile along the interval during the step of injecting the non-reactive fluid;

injecting a fluid reactive to the one or more formation zones into the well and into one or more formation zones surrounding the interval pursuant to the calculating the injectivity step;

shutting-in the well until the temperature in the well substantially stabilizes;

monitoring the shut-in temperature along the interval during the shut-in period;

determining the shut-in temperature deviation relative to the baseline temperature profile across the interval; and

determining the one or mare formation zones in which the injected fluid flowed.

15. The method of claim 14, further comprising the step of determining the shut-in temperature deviation relative to the differential temperature profile measured prior to the shut-in.

16. The method of claim 14, further including the step of injecting a diverter into the well pursuant to the step of determining the injectivity of the one or more formation zones relative to the injecting of the non-reactive fluid.

17. The method of claim 14, further comprising the step of determining the volume of the reactive fluid injected into the one or more zones.

18. The method of claim 14, further including the step of injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.

19. The method of claim 14, further including the steps of:

injecting a diverter into the well pursuant to the step of determining the zone of injection of the prior injected fluid; and

injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.

20. The method of claim 14, further including the steps of:

injecting a diverter into the well pursuant to the step of determining the one or more formation zones of injection of the prior injected reactive fluid; and

injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected reactive fluid.