Natural fracture injection test

Patent metadata

Field	Value
Publication number	US-9366122-B2
Application number	US-201213591745-A
Country	US
Kind code	B2
Filing date	Aug 22, 2012
Priority date	Aug 22, 2012
Publication date	Jun 14, 2016
Grant date	Jun 14, 2016

Abstract

A method for estimating a property of an earth formation penetrated by a borehole includes: performing a borehole integrity test at a pressure less than a fracture gradient pressure of the formation to provide leakage data; injecting a fluid into the formation at a first pressure greater than the fracture gradient pressure during a first injection time interval using a fluid injector; measuring pressure versus time using a pressure sensor and a timer during a first test time interval to provide first pressure data; injecting a fluid into the formation at a second flow rate greater than the first flow rate during a second injection time interval using the fluid injector; measuring pressure versus time using the pressure sensor and the timer during a second test time interval to provide second pressure data; and estimating the property using the first pressure data, the second pressure data, and the leakage data.

First claim

What is claimed is:

1. A method for estimating a property of an earth formation penetrated by a borehole, the method comprising:
performing a borehole integrity test at a pressure less than a fracture gradient pressure of the formation wherein the fracture gradient pressure is a pressure at which pre-existing rock fractures in the earth formation will open and begin to accept fluid, the borehole integrity test providing leakage data, the borehole integrity test comprising injecting a fluid into the formation using a fluid injector at an integrity test flow rate that is low enough so that the fracture gradient pressure of the formation is not exceeded;
injecting a fluid into the formation at a first pressure greater than the fracture gradient pressure at a first flow rate during a first injection time interval using the fluid injector;
measuring pressure versus time using a pressure sensor and a timer during a first test time interval after the injecting for the first injection time interval to provide first pressure data;
injecting a fluid into the formation at a second flow rate greater than the first flow rate during a second injection time interval using the fluid injector;
measuring pressure versus time using the pressure sensor and the timer during a second test time interval after the injecting for the second injection time interval to provide second pressure data;
monitoring a fluid temperature in the borehole using a temperature sensor;
correcting the first pressure data and the second pressure data for fluid temperature variations using the monitored fluid temperature;
correcting the leakage data for fluid temperature variations using the monitored fluid temperature;
estimating the property using the corrected first pressure data, the corrected second pressure data, and the corrected leakage data using a processor;
estimating a hydraulic stimulation pressure to stimulate the formation using the corrected first pressure data, the corrected second pressure data, and the corrected leakage data; and
hydraulically stimulating the earth formation using the estimated hydraulic stimulation pressure.

2. The method according to claim 1 , wherein the property is permeability or injectivity.

3. The method according to claim 1 , wherein at least one selection from a group consisting of the first injection time interval and the second injection time interval is twenty-four hours or less.

4. The method according to claim 1 , wherein the first flow rate is less than one barrel per minute of the fluid injected during the first injection time interval and the first injection time interval is less than one minute.

5. The method according to claim 4 , wherein the first flow rate is in a range of 0.1 to 0.5 barrels per minute and the first injection time interval is in a range of ten to fifteen seconds.

6. The method according to claim 5 , wherein the second flow rate is in a range of one to two barrels per minute and the first injection time interval is in a range of ten to fifteen seconds.

7. The method according to claim 1 , further comprising:
injecting a fluid into the formation at a third flow rate greater than the second flow rate during a third time interval using the fluid injector;
measuring pressure versus time using the pressure sensor and the timer during a third test time interval after the injecting for the third injection time interval to provide third pressure data using the pressure sensor; and
estimating the property additionally using the third pressure data.

8. The method according to claim 7 , wherein the third flow rate is greater than two barrels per minute of the fluid injected during the third injection time interval.

9. The method according to claim 8 , wherein the third flow rate is in a range of five to seven barrels per minute.

10. The method according to claim 1 , further comprising:
injecting a fluid into the formation at a fourth flow rate less than the second flow rate during a fourth time interval using the fluid injector;
measuring pressure versus time using the pressure sensor and the timer during a fourth test time interval after the injecting for the fourth injection time interval to provide fourth pressure data; and
estimating the property additionally using the fourth pressure data.

11. An apparatus for estimating a property of an earth formation penetrated by a borehole, the apparatus comprising:
a fluid injector configured to inject fluid through the borehole into the formation at a selected flow rate;
a pressure sensor configured to sense pressure of a fluid in the borehole;
a timer configured to measure a time interval; and
a temperature sensor configured to monitor a borehole fluid temperature; and
a processor configured to:
receive leakage data from a borehole integrity test conducted at a pressure less than a fracture gradient pressure of the formation using the fluid injector wherein the fracture gradient pressure is a pressure at which pre-existing rock fractures in the earth formation will open and begin to accept fluid and the borehole integrity test comprises injecting a fluid into the formation using the fluid injector at an integrity test flow rate that is low enough so that the fracture gradient pressure of the formation is not exceeded;
receive first pressure data comprising a pressure versus time measurement obtained using the pressure sensor and the timer during a first test time interval after injecting a fluid into the formation at a first pressure greater than the fracture gradient pressure at a first flow rate during a first injection time interval using the fluid injector;
receive second pressure data comprising a pressure versus time measurement obtained using the pressure sensor and the timer during a second test time interval after injecting a fluid into the formation at a second flow rate greater than the first flow rate during a second injection time interval using the fluid injector; and
correct the first pressure data and the second pressure data for fluid temperature variations using the monitored fluid temperature;
correct the leakage data for fluid temperature variations using the monitored fluid temperature;
estimate the property using the first corrected pressure data, the corrected second pressure data, and the corrected leakage data;

estimating a hydraulic stimulation pressure to stimulate the formation using the corrected first pressure data, the corrected second pressure data, and the corrected leakage data;
wherein a fluid injector for hydraulic stimulation is configured to inject a fluid into the earth formation at the estimated hydraulic stimulation pressure in order to hydraulically stimulate the earth formation.

12. The apparatus according to claim 11 , wherein the processor is further configured to:
receive third pressure data comprising a pressure versus time measurement obtained using the pressure sensor and the timer during a third test time interval after injecting a fluid into the formation at a third flow rate greater than the second flow rate during a third time interval using the fluid injector; and
estimate the property additionally using the third pressure data.

13. The apparatus according to claim 11 , wherein the processor is further configured to:
receive fourth pressure data comprising a pressure versus time measurement obtained using the pressure sensor and the timer during a fourth test time interval after injecting a fluid into the formation at a fourth flow rate that is less than the second flow rate; and
estimate the property additionally using the fourth pressure data.

14. A non-transitory computer-read

Assignees

• Anderson Christopher R L
• Moos Daniel
• Barton Colleen A
• Baker Hughes Inc

Inventors

• Anderson Christopher R L
• Moos Daniel
• Barton Colleen A

Classifications

• E21B49/008

  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 title

• E21B47/06

  Measuring temperature or pressure · CPC title

• E21B49/08

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

• E21B43/26 Primary

  by forming crevices or fractures · CPC title