Time Reverse Reservoir Localization

• US 20080175101A1
• Filed: 01/22/2008
• Published: 07/24/2008
• Est. Priority Date: 01/20/2007
• Status: Active Grant

• Current Assignee: Spectraseis Inc. (Deep Imaging Technologies Inc.)
• Original Assignee: Spectraseis AG
• Inventors: Schmalholz, Stefan, Saenger, Erik, Steiner, Brian
• Granted Patent: US 7,675,815 B2
• Time in Patent Office: Days
• US Class Current: 367/43
• CPC Class Codes: G01V 1/28 Processing seismic data, e.g. for interpretation or for event detection G01V1/48 takes precedence
• CPC Class Codes: G01V 1/301 for determining seismic cross-sections or geostructures
• CPC Class Codes: G01V 2210/123 Passive source, e.g. microseismics
• CPC Class Codes: G01V 2210/51 Migration
• CPC Class Codes: G01V 2210/67 Wave propagation modeling
• CPC Class Codes: G01V 2210/679 Reverse-time modeling or coalescence modelling, i.e. starting from receivers

Abstract

A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. These dynamic particle parameters are stored in a form for display. Maximum values of the dynamic particle parameters may be interpreted as reservoir locations. The dynamic particle parameters may be particle displacement values, particle velocity values, particle acceleration values or particle pressure values. The sensors may be three-component sensors. Zero-phase frequency filtering of different ranges of interest may be applied. The data may be resampled to facilitate efficient data processing.

Claims

1. A method for processing synchronous array seismic data comprising:

a) acquiring seismic data from a plurality of sensors to obtain synchronized array measurements;

b) selecting seismic data without reference to phase information of the seismic data;

c) applying a reverse-time data process to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with a subsurface location; and

d) storing at least one of the plurality of dynamic particle parameters in a form for display.

2. The method of claim 1 wherein the stored value is a maximum value of the plurality of dynamic particle parameters.

3. The method of claim 1 wherein the plurality of dynamic particle parameters are at least one selected from the group consisting of i) particle velocity values, ii) particle acceleration values and iii) particle pressure values.

4. The method of claim 1 wherein the plurality of sensors are three-component sensors.

5. The method of claim 1 further comprising applying a zero-phase frequency filter to the synchronized array measurements.

6. The method of claim 1 further comprising resampling the synchronized array measurements.

7. The method of claim 1 further comprising an extrapolator selected from a group consisting of i) finite-difference reverse time migration, ii) ray-tracing reverse time migration and iii) pseudo-spectral reverse time migration.

8. A set of application program interfaces embodied on a computer readable medium for execution on a processor in conjunction with an application program for applying a reverse-time data process to continuous synchronized seismic data array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations comprising:

a first interface that receives synchronized seismic data array measurements; and

a second interface that receives a maximum value of the plurality of dynamic particle parameters associated with a subsurface location, the value output from reverse-time data processing of the synchronized seismic data array measurements.

9. The set of application interface programs according to claim 8 further comprising:

a third interface that receives instruction data for applying a zero-phase frequency filter to the synchronized array measurements.

10. The set of application interface programs according to claim 8 further comprising:

a fourth interface that receives instruction data for displaying maximum values of the plurality of dynamic particle parameters.

11. The set of application interface programs according to claim 8 further comprising:

a fifth interface that receives instruction data for resampling the synchronized seismic data array measurements.

12. The set of application interface programs according to claim 8 further comprising:

a sixth interface that receives instruction data for the plurality of dynamic particle parameters that are at least one selected from the group consisting of i) particle velocity values, and ii) particle acceleration values and iii) particle pressure values.

13. The set of application interface programs according to claim 8 further comprising:

a seventh interface that receives instructions data for processing using a velocity structure.

14. The set of application interface programs according to claim 8 further comprising:

an eighth interface that receives instructions data for including an extrapolator for at least one selected from the group of i) finite-difference reverse time migration, ii) ray-tracing reverse time migration and iii) pseudo-spectral reverse time migration.

15. An information handling system for determining the presence of subsurface hydrocarbons associated with an area of seismic data acquisition comprising:

a) a processor configured for applying a reverse-time data process to synchronized array measurements of seismic data to obtain a plurality of dynamic particle parameters associated with subsurface locations; and

b) a computer readable medium for storing at least one of the plurality of dynamic particle parameters.

16. The information handling system of claim 15 wherein the processor is configured to apply the reverse-time data process with predetermined subsurface velocity information associated with subsurface locations.

17. The information handling system of claim 15 further comprising a display device for displaying the dynamic particle parameters.

18. The information handling system of claim 15 wherein the stored parameter is a maximum value of the plurality of dynamic particle parameters.

19. The information handling system of claim 15 wherein the processor is configured to apply the reverse-time data process with an extrapolator for at least one selected from the group of i) finite-difference reverse time migration, ii) ray-tracing reverse time migration and iii) pseudo-spectral reverse time migration.

20. The information handling system of claim 15 further comprising:

a graphical display coupled to the processor and configured to present a view of the ratio as a function of position, wherein the processor is configured to generate the view by contouring the ratio over an area associated with the seismic data.