Reservoir fluid geodynamic system and method for reservoir characterization and modeling

Patent metadata

Field	Value
Publication number	US-10746017-B2
Application number	US-201615165798-A
Country	US
Kind code	B2
Filing date	May 26, 2016
Priority date	May 29, 2015
Publication date	Aug 18, 2020
Grant date	Aug 18, 2020

Abstract

A method includes receiving first fluid property data from a first location in a hydrocarbon reservoir and receiving second fluid property data from a second location in the hydrocarbon reservoir. The method includes performing a plurality of realizations of models of the hydrocarbon reservoir according to a respective plurality of one or more plausible dynamic processes to generate one or more respective modeled fluid properties. The method includes selecting the one or more plausible dynamic processes based at least in part on a relationship between the first fluid property data, the second fluid property data, and the modeled fluid properties obtained from the realizations to identify potential disequilibrium in the hydrocarbon reservoir.

First claim

What is claimed is:

1. A method comprising:
receiving first fluid property data from a first location in a hydrocarbon reservoir;
receiving second fluid property data from a second location in the hydrocarbon reservoir, wherein the first and second fluid property data is measured using a downhole acquisition tool;
performing, using a processor, a plurality of realizations of models of the hydrocarbon reservoir according to a respective plurality of dynamic processes to generate one or more respective modeled fluid properties, wherein the plurality of dynamic processes comprises a range of possible dynamic processes occurring within the hydrocarbon reservoir;
selecting, using the processor, one or more dynamic processes of the plurality of dynamic processes that is more likely to be occurring within the hydrocarbon reservoir compared to other dynamic processes in the plurality of dynamic processes based at least in part on a relationship between the first fluid property data, the second fluid property data, and the modeled fluid properties obtained from the realizations to identify potential disequilibrium in the hydrocarbon reservoir; and
identifying, using the processor, disequilibrium in the hydrocarbon reservoir resulting from the selected one or more dynamic processes, wherein identifying the disequilibrium occurs after selecting the one or more dynamic processes of the plurality of dynamic processes.

2. The method of claim 1 , comprising identifying, using the processor, a first fluid gradient from the first and second fluid property data.

3. The method of claim 2 , wherein selecting the one or more plausible dynamic processes comprises establishing a relationship between the first fluid gradient and the modeled fluid properties obtained from one of the realizations modeled according to the one or more plausible dynamic processes that is selected.

4. The method of claim 2 , wherein the first fluid gradient comprises a gas-to-oil ratio gradient, a viscosity gradient, a gravity gradient, a density gradient, an asphaltene content gradient, or any combination thereof.

5. The method of claim 2 , comprising selecting, using the processor, at least one realization scenario from among the range of dynamic processes that is more likely to be causing the disequilibrium in the hydrocarbon reservoir compared to other realization scenarios in the range of dynamic processes based on a relationship between the one or more modeled fluid properties and the first fluid gradient.

6. The method of claim 5 , wherein selecting the at least one realization scenario comprises determining a relationship between the first fluid gradient of the first fluid property data and the modeled fluid gradient.

7. The method of claim 5 , comprising predicting, using the processor, a location within the hydrocarbon reservoir where the one or more dynamic processes takes place based at least in part on the modeling of the hydrocarbon reservoir according to the at least one likely realization scenario.

8. The method of claim 5 , wherein selecting the at least one realization scenario comprises determining number of fluid obstructions, a location of fluid obstructions, or a combination thereof.

9. The method of claim 8 , wherein the location comprises a depth of the wellbore.

10. The method of claim 1 , comprising operating the downhole acquisition tool in the hydrocarbon reservoir to measure the first fluid property data of the hydrocarbon reservoir.

11. The method of claim 1 , comprising determining, using the processor, an enhanced oil recovery technique, pressure maintenance, or both, based on the one or more plausible dynamic process.

12. The method of claim 1 , wherein modeling the hydrocarbon reservoir comprises modeling fluid of the hydrocarbon reservoir according to an equation of state, wherein the equation of state comprises a diffusive model or a convective model associated with each respective realization scenario of the one or more plausible dynamic processes.

13. The method of claim 1 , wherein the plurality of dynamic processes comprises hydrocarbon biodegradation, gas diffusion, fault block migration, or subsidence, or any combination thereof.

Assignees

• Schlumberger Technology Corp

Inventors

• Zuo Youxiang
• Wang Kang
• Pomerantz Andrew E
• Betancourt Pocaterra Soraya S
• Forsythe Jerimiah
• Ayan Cosan
• Dumont Hadrien
• Mishra Vinay
• Canas Jesus Alberto
• Tetzlaff Daniel M
• Kumar Anish
• Achourov Vladislav
• Pfeiffer Thomas
• Pan Shu
• Chen Yi
• Kauerauf Armin
• Mullins Oliver C

Classifications

• E21B47/10

  Locating fluid leaks, intrusions or movements · CPC title

• E21B49/08 Primary

  Obtaining fluid samples or testing fluids, in boreholes or wells · CPC title