Methods and apparatus for determining fluid parameters

Patent metadata

Field	Value
Publication number	US-9804291-B2
Application number	US-201214125293-A
Country	US
Kind code	B2
Filing date	Jun 13, 2012
Priority date	Jun 13, 2011
Publication date	Oct 31, 2017
Grant date	Oct 31, 2017

Abstract

Example methods and apparatus for determining fluid parameters are disclosed herein. An example method includes disposing a sensor in a first fluid flow passageway. The sensor has a heater and a temperature sensor. The example method further includes flowing a first fluid into the first fluid flow passageway via a second fluid flow passageway and determining a first fluid property value of the first fluid via the sensor when the first fluid is in the first fluid flow passageway. Based on the first fluid property value, a state of an operation is determined.

First claim

What is claimed is:

1. A method for performing an operation in a wellbore, comprising:
disposing a downhole tool in a wellbore via a coiled tubing, the downhole tool including a treatment tool, a first sensor and a second sensor, the first sensor having a first heater and a first temperature sensor, the second sensor having a second heater and a second temperature sensor;
performing the operation by flowing a treatment fluid into the wellbore from inside the coiled tubing and the downhole tool through the treatment tool;
determining a first fluid property value of the treatment fluid via the first sensor when the treatment fluid is inside the downhole tool;
determining a second fluid property value of the treatment fluid via the second sensor when the treatment fluid is in the wellbore outside of the downhole tool;
determining a state of the operation based on a difference between the determined first fluid property value and the determined second fluid property value; and
controlling the operation based on the determined state of the operation.

2. The method of claim 1 wherein flowing the first fluid into the wellbore comprises pumping mud through a portion of the downhole tool.

3. The method of claim 1 wherein determining the first fluid property value comprises determining a first density of the fluid and determining the second fluid property value comprises determining a second density of the fluid.

4. The method of claim 1 wherein determining the first fluid property value comprises determining a first thermal property value of the fluid and determining the second fluid property value comprises determining a second thermal property value of the fluid.

5. The method of claim 1 wherein flowing the fluid into the wellbore comprises flowing a chemical mixture into the wellbore to cause a chemical reaction in the wellbore.

6. The method of claim 5 wherein determining the second fluid property value comprises determining a characteristic of one of a bubble or foam in the fluid produced from the chemical reaction of the chemical mixture.

7. The method of claim 1 wherein the first and second sensors each comprise a calorimetric flow type sensor.

8. The method of claim 1 further comprising determining where the treatment fluid is flowing during the treatment.

9. The method of claim 1 further comprising retrieving the coiled tubing, downhole tool and treatment well after the operation is performed.

10. A method, comprising:
disposing a downhole tool in a wellbore via a coiled tubing, the downhole tool including a treatment tool, a first sensor, and a second sensor, each of the sensors having a heater and a temperature sensor;
determining a first fluid property value of a first fluid via the first sensor, the first fluid disposed in the wellbore adjacent the downhole tool;
flowing a second fluid into the wellbore from inside the coiled tubing and the downhole tool through the treatment tool;
determining a second fluid property value of the second fluid via the second sensor while flowing the second fluid into the wellbore;
determining a third fluid property value of the first fluid when the second fluid is inside the downhole tool via the second sensor;
determining a state of a downhole operation based a difference between at least one of the first fluid property value, the second fluid property value, and the third fluid property value; and
controlling the downhole operation based on the determined state of the operation.

11. The method of claim 10 wherein determining the first fluid property value comprises determining a first density of the first fluid and wherein determining the second fluid property value comprises determining a second density of the first fluid.

12. The method of claim 10 wherein determining the first fluid property value comprises determining a first thermal property value of the first fluid and wherein determining the second fluid property value comprises determining a second thermal property value of the first fluid.

13. The method of claim 10 wherein flowing the second fluid into the wellbore comprises pumping mud through a portion of the downhole tool.

14. The method of claim 10 wherein flowing the second fluid into the wellbore comprises flowing a chemical mixture into the wellbore to cause a chemical reaction in the wellbore.

15. The method of claim 10 further comprising monitoring the flow of the second fluid in real-time.

16. The method of claim 10 wherein the first and second sensors each comprise a calorimetric flow type sensor.

Assignees

• Adil Abdur Rahman
• Borisova Elena
• Moscato Tullio
• Schlumberger Technology Corp

Inventors

• Adil Abdur Rahman
• Borisova Elena
• Moscato Tullio

Classifications

• E21B47/07

  Temperature · CPC title

• E21B47/103

  using thermal measurements · CPC title

• G01V9/005 Primary

  by thermal methods, e.g. after generation of heat by chemical reactions · CPC title

• E21B49/08

  Obtaining fluid samples or testing fluids, in boreholes or wells · CPC title

• E21B47/1005

  Fixed Constructions · mapped topic