METHOD FOR TESTING AN ENGINEERED GEOTHERMAL SYSTEM USING ONE STIMULATED WELL

• US 20100032156A1
• Filed: 08/10/2009
• Published: 02/11/2010
• Est. Priority Date: 08/08/2008
• Status: Abandoned Application

• Current Assignee: AltaRock Energy, Inc.
• Original Assignee: Alta Rock Energy Incorporated
• Inventors: Nofziger, Laura, PETTY, SUSAN, Rose, Peter E.
• Application Number:
  US12/538,673
• Publication Number:
  US 20100032156A1
• Time in Patent Office: Days
• US Class Current: 166/252.100
• CPC Class Codes: E21B 43/26 by forming crevices or fractures
• 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: F24T 10/00 Geothermal collectors
• CPC Class Codes: F24T 10/30 using underground reservoirs for accumulating working fluids or intermediate fluids
• CPC Class Codes: F24T 2201/00 Prediction; Simulation
• CPC Class Codes: Y02E 10/10 Geothermal energy

Abstract

Systems and methods for testing a subterranean formation are herein disclosed. According to one embodiment, a method includes stimulating a substantially non-permeable medium within a subterranean formation to create a fractured reservoir. At least one stimulation parameter is measured during stimulation. A well drilled in the subterranean formation is shut-in. A fluid is produced from the subterranean well and at least one production parameter is measured during production. The stimulation and production parameters are used in a numerical reservoir fluid flow model to identify parameters of the fractured reservoir.

Claims

1. A method comprising:

stimulating a substantially non-permeable medium within a subterranean formation to create a fractured reservoir;

measuring at least one stimulation parameter during stimulation;

using the stimulation parameter in a numerical reservoir fluid flow model;

shutting-in a subterranean well drilled in the subterranean formation;

producing a fluid comprising at least a treatment fluid from the subterranean well;

measuring at least one production parameter during production;

using the production parameter in the numerical reservoir fluid flow model; and

identifying a heat exchange area of the fractured reservoir using the numerical reservoir fluid flow model.

2. The method as recited in claim 1, wherein stimulating a substantially non-permeable medium within the subterranean formation comprises injecting the treatment fluid into the subterranean formation.

3. The method as recited in claim 2, wherein measuring at least one stimulation parameter during stimulation comprises measuring at least one parameter from a group consisting of:

seismicity within the subterranean formation, streaming potential of the treatment fluid injected into the subterranean formation, temperature within the subterranean well and pressure within the subterranean well.

4. The method as recited in claim 2, wherein the treatment fluid comprises a tracer composition.

5. The method as recited in claim 4, wherein the tracer composition comprises at least one reactive tracer and at least one nonreactive tracer.

6. The method as recited in claim 5, wherein measuring at least one production parameter during production comprises measuring at least one parameter from a group consisting of:

flow rate of the fluid produced from the subterranean well, concentration of the at least one reactive tracer, concentration of the at least one nonreactive tracer, temperature within the subterranean well, and pressure within the subterranean well.

7. The method as recited in claim 2, further comprising injecting a test fluid into the subterranean formation.

8. The method as recited in claim 7, wherein measuring at least one stimulation parameter during stimulation comprises measuring at least one parameter from a group consisting of:

seismicity within the subterranean formation, streaming potential of the treatment fluid injected into the subterranean formation, temperature within the subterranean well and pressure within the subterranean well.

9. The method as recited in claim 8, further comprising measuring at least one injection parameter during injection.

10. The method as recited in claim 9, wherein measuring at least one injection parameter during injection comprises measuring at least one parameter from a group consisting of:

seismicity within the subterranean formation, streaming potential of the test fluid injected into the subterranean formation, temperature within the subterranean well and pressure within the subterranean well.

11. The method as recited in claim 10, wherein the test fluid comprises a tracer composition.

12. The method as recited in claim 11, wherein the tracer composition comprises at least one reactive tracer and at least one nonreactive tracer.

13. The method as recited in claim 12, wherein producing a fluid further comprises producing a fluid comprising at least the test fluid from the subterranean well.

14. The method as recited in claim 13, wherein measuring at least one production parameter during production comprises measuring at least one parameter from a group consisting of:

flow rate of the fluid produced from the subterranean well, concentration of the at least one reactive tracer, concentration of the at least one nonreactive tracer, temperature within the subterranean well, and pressure within the subterranean well.

15. A computer program product comprising:

at least one computer-readable medium;

at least one processor module residing on the computer-readable medium and operative to;

use an input of test data obtained from testing a subterranean formation in a numerical reservoir fluid flow model; and

provide an output of theoretical data generated by the numerical reservoir fluid flow model.

16. The computer program product as recited in claim 15, wherein the subterranean formation comprises at least one subterranean interval.

17. The computer program product as recited in claim 16, wherein the subterranean formation is stimulated by injecting treatment fluid into the at least one subterranean interval to create a fractured reservoir.

18. The computer program product as recited in claim 17, wherein the treatment fluid comprises a tracer composition comprising at least one reactive tracer and at least one nonreactive tracer.

19. The computer program product as recited in claim 18, wherein the input of test data obtained from testing the subterranean formation comprises at least one parameter from a group consisting of:

seismicity within the subterranean formation, streaming potential of the treatment fluid injected into the at least one subterranean interval, temperature adjacent to the at least one subterranean interval, pressure proximate the bottom of the fractured reservoir, flow rate of the treatment fluid produced from the at least one subterranean interval, concentration of the at least one reactive tracer, concentration of the at least one nonreactive tracer.

20. The computer program product as recited in claim 19, wherein the output of theoretical data venerated by the numerical reservoir fluid flow model comprises at least one parameter from a group consisting of:

heat exchange area of the at least one subterranean interval, circulating volume of the treatment fluid within the at least one subterranean interval, permeability of the at least one subterranean interval, porosity of the at least one subterranean interval, combined compressibility of the at least one subterranean interval and thickness of the at least one subterranean interval.