Apparatus and method for increasing the ultimate recovery of natural gas contained in shale and other tight gas reservoirs

• US 8,924,029 B2
• Filed: 11/14/2011
• Issued: 12/30/2014
• Est. Priority Date: 02/23/2011
• Status: Expired due to Fees

• Current Assignee: Honeywell International Inc.
• Original Assignee: Honeywell International Inc.
• Inventors: Nath, Ravi, Sharma, Sanjay Kumar, Renfro, Jeffrey G., Stanek, Jerome J.
• Primary Examiner(s): Masinick, Michael D
• Application Number:
  US13/295,746
• Publication Number:
  US 20120215365A1
• Time in Patent Office: 1,142 Days
• Field of Search: 700/282, 700/285, 166/386, 166/316, 166/266, 166/344, 166/320, 702 45- 49, 703/10
• US Class Current: 700/282
• CPC Class Codes: E21B 43/00 Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells applicable only to water E03B
• CPC Class Codes: E21B 43/34 Arrangements for separating materials produced by the well
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: G05B 13/04 involving the use of models or simulators
• CPC Class Codes: G06F 30/28 using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]

Abstract

A method includes obtaining a model associated with production of natural gas from a well, where the well has a choke valve that controls flow of material including natural gas from the well. The method also includes identifying, using the model, a solution that increases an amount of natural gas obtained from the well over a specified time horizon. In addition, the method includes adjusting operation of the choke valve based on the identified solution. The model could be generated using geological data associated with the well and/or historical data associated with natural gas production from the well. A natural gas reservoir can be modeled as a continuous stirred bed with a rock or shale void fraction using mass or volumetric unit balances. Gas content versus pressure for the well can be plotted, and Langmuir adsorption parameters for the well can be identified using the plotted gas content versus pressure.

Claims

1. A method comprising:

obtaining a model associated with production of natural gas from a well, the well having a choke valve that controls flow of material including natural gas from the well;

identifying, using the model, a solution that increases an amount of natural gas obtained from the well over a specified time horizon; and

adjusting operation of the choke valve based on the identified solution;

wherein the model models a natural gas reservoir as a continuous stirred bed with a rock or shale void fraction.

2. The method of claim 1, wherein identifying the solution comprises at least one of:

identifying an optimal production rate for the well;

or

identifying an optimal choke valve setting for the well.

3. The method of claim 1, wherein identifying the solution comprises determining how to adjust the choke valve to maximize natural gas production over the specified time horizon, the specified time horizon being at least one year in length.

4. The method of claim 1, wherein obtaining the model comprises generating the model using at least one of:

geological data associated with the well or historical data associated with natural gas production from the well.

5. The method of claim 1, wherein obtaining the model comprises generating the model using mass or volumetric unit balances.

6. The method of claim 5, wherein generating the model further comprises plotting gas content versus pressure for the well and identifying Langmuir adsorption parameters for the well using the plotted gas content versus pressure.

7. The method of claim 1, wherein adjusting the operation of the choke valve comprises adjusting an opening of the choke valve using a valve actuator.

8. An apparatus comprising:

at least one memory device configured to store a model associated with production of natural gas from a well that has a choke valve for controlling flow of material including natural gas from the well; and

at least one processing device configured to;

identify, using the model, a solution that increases an amount of natural gas obtained from the well over a specified time horizon; and

adjust operation of the choke valve based on the identified solution;

wherein the model models a natural gas reservoir as a continuous stirred bed with a rock or shale void fraction.

9. The apparatus of claim 8, wherein the at least one processing device is configured to identify the solution by at least one of:

identifying an optimal production rate for the well;

or

identifying an optimal choke valve setting for the well.

10. The apparatus of claim 8, wherein the at least one processing device is configured to identify the solution by determining how to adjust the choke valve to maximize natural gas production over the specified time horizon, the specified time horizon being at least one year in length.

11. The apparatus of claim 8, wherein the at least one processing device is configured to generate the model using at least one of:

geological data associated with the well or historical data associated with natural gas production from the well.

12. The apparatus of claim 8, wherein the at least one processing device is configured to generate the model using mass or volumetric unit balances.

13. The apparatus of claim 12, wherein the at least one processing device is configured to generate the model further by plotting gas content versus pressure for the well and identifying Langmuir adsorption parameters for the well using the plotted gas content versus pressure.

14. The apparatus of claim 8, wherein the at least one processing device is configured to adjust the operation of the choke valve by interacting with a valve actuator that is configured to adjust an opening of the choke valve.

15. A non-transitory computer readable medium embodying a computer program, the computer program comprising computer readable program code for:

obtaining a model associated with production of natural gas from a well having a choke valve that controls flow of material including natural gas from the well;

identifying, using the model, a solution that increases an amount of natural gas obtained from the well over a specified time horizon; and

adjusting operation of the choke valve based on the identified solution

wherein the model models a natural gas reservoir as a continuous stirred bed with a rock or shale void fraction.

16. The computer readable medium of claim 15, wherein the computer readable program code for identifying the solution comprises computer readable program code for at least one of:

identifying an optimal production rate for the well;

or

identifying an optimal choke valve setting for the well.

17. The computer readable medium of claim 15, wherein the computer readable program code for identifying the solution comprises computer readable program code for determining how to adjust the choke valve to maximize natural gas production over the specified time horizon, the specified time horizon being at least one year in length.

18. The computer readable medium of claim 15, wherein the computer readable program code for obtaining the model comprises computer readable program code for generating the model using at least one of:

geological data associated with the well or historical data associated with natural gas production from the well.

19. The computer readable medium of claim 15, wherein:

the computer readable program code for obtaining the model comprises computer readable program code for generating the model; and

the computer readable program code for generating the model comprises computer readable program code for using mass or volumetric unit balances.

20. The computer readable medium of claim 19, wherein the computer readable program code for generating the model comprises computer readable program code for plotting gas content versus pressure for the well and identifying Langmuir adsorption parameters for the well using the plotted gas content versus pressure.