Transport Property Data Calculated From Derivative Seismic Rock Property Data For Transport Modeling

• US 20110015912A1
• Filed: 04/13/2009
• Published: 01/20/2011
• Est. Priority Date: 05/06/2008
• Status: Active Grant

• Current Assignee: Jonathan Stewart, Michael E. Farrell, Rene Jonk, Scott A. Barboza, Shauna K. Oppert
• Original Assignee: Jonathan Stewart, Michael E. Farrell, Rene Jonk, Scott A. Barboza, Shauna K. Oppert
• Inventors: Farrell, Michael E., Barboza, Scott A., Oppert, Shauna K., Stewart, Jonathan, Jonk, Rene
• Granted Patent: US 8,688,425 B2
• Time in Patent Office: Days
• US Class Current: 703/10
• CPC Class Codes: G01V 99/00 Subject matter not provided for in other groups of this subclass

Abstract

At least one transport property for a subsurface region is calculated from derivative seismic data by generating a model relating at least one derivative seismic rock property of a subsurface region to at least one transport property for the subsurface region. At least one transport property is calculated by applying the generated transport property model. Transport phenomena may be simulated with a transport model using at least one transport property generated by applying the model. A model describing evolution of the at least one transport property may be generated within the subsurface region over time, e.g., to facilitate basin modeling of the subsurface region.

Claims

1. A method for calculating at least one transport property for a subsurface region from derivative seismic data, the method comprising:

generating a model relating at least one derivative seismic rock property of a subsurface region to at least one transport property for the subsurface region; and

calculating the at least one transport property by applying the generated model.

2. The method of claim 1, further comprising simulating transport phenomena with a transport model using at least one transport property calculated by applying the model.

3. The method of claim 2, wherein simulating transport phenomena within the subsurface region comprises simulating reservoir fluid flow within the subsurface region using a permeability property of the subsurface region.

4. The method of claim 2, wherein simulating transport phenomena comprises simulating hydrocarbon migration within the subsurface region, wherein the transport model includes a static migration model incorporating a present-day subsurface configuration or a dynamic migration model incorporating evolution of subsurface rock and transport properties over geologic time using a capillary threshold entry pressure property of the subsurface region.

5. The method of claim 2, wherein simulating transport phenomena comprises simulating heat flow evolution within the subsurface region using a thermal conductivity property of the subsurface region.

6. The method of claim 2, wherein simulating transport phenomena comprises simulating aqueous fluid pressure evolution over time within the subsurface region using a permeability property of the subsurface region.

7. The method of claim 2, wherein simulating transport phenomena comprises simulating electrical resistivity within the subsurface region using a resistivity property of the subsurface region.

8. The method of claim 2, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to the at least one transport property for the subsurface region comprises transforming a rock property model of the subsurface region to a transport property model for the subsurface region.

9. The method of claim 1, further comprising generating a model describing evolution of the at least one transport property within the subsurface region over time.

10. The method of claim 1, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to at least one transport property for the subsurface region does not include:

relying upon production data to constrain an inversion, using a direct inversion of seismic reflection data for transport properties, using a statistical calibration to derive the relationship between lithologic or geologic parameters and seismic attributes, using only seismic attributes, using synthetic seismograms to derive petrophysical properties of the seismic data, and/or relying upon seismic velocity data.

11. The method of claim 1, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to at least one transport property for the subsurface region includes one or more of:

using seismic transport property data to populate a transport model for pressure simulations, using rock and transport properties derived from the seismic data to assist in transport modeling, and/or using seismic rock property data incorporating seismic derivatives and low frequency models.

12. The method of claim 2, further comprising comparing results from a simulated transport model to actual production data and iterating between one or more of seismic interpretation, generation of rock and flow properties, and simulating transport phenomena.

13. The method of claim 1, wherein the at least one derivative seismic rock property includes seismic Vclay data for the subsurface region and seismic porosity data for the subsurface region.

14. The method of claim 13, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to the at least one transport property for the subsurface region comprises:

combining the seismic Vclay data and the seismic porosity data into a lithofacies property for the subsurface region, and

converting the lithofacies property into a transport property model for permeability and effective or total porosity for the subsurface region.

15. The method of claim 14, wherein combining the seismic Vclay data and the seismic porosity data into the lithofacies property for the subsurface region comprises cross-plotting seismic porosity and Vclay for the subsurface region.

16. The method of claim 14, wherein the total porosity and Vclay are used to locally discriminate between a plurality of potential lithofacies associations for the subsurface region.

17. The method of claim 16, wherein converting the lithofacies property into the transport property comprises using empirical relationships to calculate flow properties for each lithofacies association.

18. The method of claim 17, further comprising deriving the empirical relationships from measured well data and/or from predetermined theoretical derivations.

19. The method of claim 17, further comprising simulating transport phenomena with a transport model using at least one generated transport property, wherein simulating transport phenomena within the subsurface region comprises simulating reservoir fluid flow within the subsurface region using the permeability property of the subsurface region.

20. The method of claim 19, further comprising comparing results from a simulated transport model to actual production data and iterating between one or more of seismic interpretation, generation of rock and flow properties, and simulating transport phenomena.

21. The method of claim 13, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to at least one transport property for the subsurface region comprises:

calculating a permeability property for the subsurface region directly from the Vclay and porosity data, and

converting the permeability property into a transport property model for capillary threshold entry pressure (MICP) for the subsurface region.

22. The method of claim 21, further comprising simulating transport phenomena with the capillary threshold entry pressure (MICP) for the subsurface region, including simulating hydrocarbon migration within the subsurface region with a migration simulator, wherein the transport model includes a static migration model or a dynamic migration model using a capillary threshold entry pressure property of the subsurface region.

23. The method of claim 21, wherein the at least one derivative seismic rock property includes seismic Vclay data for the subsurface region.

24. The method of claim 23, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to the at least one transport property for the subsurface region comprises:

determining a grain size distribution property for the seismic Vclay data, wherein silt and sand distribution is associated with each clay percentage within the seismic Vclay data;

determining compaction history by defining a relationship between effective stress and porosity; and

converting the compaction history and the grain size distribution property into a transport property model for capillary threshold entry pressure (MICP) over time for the subsurface region.

25. The method of claim 1, wherein the at least one derivative seismic rock property includes seismic Vclay data for the subsurface region.

26. The method of claim 25, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to the at least one transport property for the subsurface region comprises:

determining a grain size distribution property for the seismic Vclay data, wherein silt and sand distribution is associated with each clay percentage within the seismic Vclay data;

determining compaction history by defining a relationship between effective stress and porosity; and

converting the compaction history and the grain size distribution property into a transport property model for thermal conductivity over time for the subsurface region.

27. The method of claim 1, wherein the at least one derivative seismic rock property includes a seismic Vclay property for the subsurface region and a seismic lithofacies property for the subsurface region.

28. The method of claim 27, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to the at least one transport property for the subsurface region comprises, the method comprising:

determining a grain size distribution definition for each lithofacies from a combination of the seismic Vclay property and the seismic lithofacies property;

determining compaction history by defining a relationship between effective stress and porosity; and

converting the compaction history and the grain size distribution property into a transport property model for permeability over time for the subsurface region.

29. The method of claim 13, wherein generating the model relating at least one derivative seismic rock property of the subsurface region to the at least one transport property for the subsurface region comprises:

determining fluid type across the subsurface region based upon a seismic fluid prediction determined from an AVO analysis or based on a migration simulation result;

determining a calculated resistivity property for the subsurface region based upon the seismic Vclay property, the seismic porosity property, and the determined fluid type; and

confirming resistive, subsurface hydrocarbon accumulations by comparing the calculated resistivity property for the subsurface region to empirical resistivity data representative of, or acquired from, the subsurface region.

30. A method for determining at least one transport property for a subsurface region from derivative seismic data, the method comprising:

generating a model relating at least one derivative seismic rock property of a subsurface region to at least one transport property for the subsurface region;

generating a model describing evolution of the at least one transport property within the subsurface region over time;

calculating the at least one transport property by applying the generated model relating the at least one derivative seismic rock property to the at least one transport property; and

simulating transport phenomena with a transport model using the at least one transport property calculated by applying the model.

31. The method of claim 30, wherein simulating transport phenomena includes simulating evolution of the transport phenomena over geologic time.

32. A tangible computer-readable storage medium having embodied thereon a computer program configured to, when executed by a processor, calculate at least one transport property for a subsurface region based on derivative seismic data, the medium comprising one or more code segments configured to:

generate a model relating at least one derivative seismic rock property of the subsurface region to at least one transport property for the subsurface region; and

calculate the at least one transport property by applying the generated model.

33. The tangible computer-readable storage medium of claim 32, further comprising one or more code segments configured to:

simulate transport phenomena with a transport model using the at least one transport property calculated by applying the model.

34. The tangible computer-readable storage medium of claim 32, further comprising one or more code segments configured to:

generate a model describing evolution of the at least one transport property within the subsurface region over time.

35. The tangible computer-readable storage medium of claim 34, wherein the code segments configured to simulate transport phenomena simulate evolution of the transport phenomena over geologic time.

36. A method for producing hydrocarbons from a subsurface region, comprising:

determining at least one transport property for the subsurface region from derivative seismic data, wherein determining the at least one transport property includes;

generating a model relating at least one derivative seismic rock property of a subsurface region to at least one transport property for the subsurface region; and

calculating the at least one transport property by applying the generated model;

simulating transport phenomena with a transport model using the at least one transport property generated by applying the model; and

controlling production of a hydrocarbon bearing reservoir based on the simulated transport phenomena; and

producing hydrocarbons from the hydrocarbon bearing reservoir.