Time reverse reservoir localization

• US 7,675,815 B2
• Filed: 01/22/2008
• Issued: 03/09/2010
• 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
• Primary Examiner(s): Keith; Jack W.
• Assistant Examiner(s): BREIER, KRYSTINE E
• Application Number:
  US12/017,527
• Publication Number:
  US 20080175101A1
• Time in Patent Office: 777 Days
• Field of Search: 367 37- 39, 367/50, 367/51
• US Class Current: 367/38
• 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 using a processing unit to the synchronized array measurements to obtain a dynamic particle parameter associated with a plurality of subsurface locations; and

d) storing only a maximum value and discarding any other value, of the dynamic particle parameter associated with each of the plurality of subsurface locations.

2. The method of claim 1 wherein the maximum value of dynamic particle parameters is stored in a form for display.

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.