Hydrocarbon determination in unconventional shale

Patent metadata

Field	Value
Publication number	US-10488545-B2
Application number	US-201816138384-A
Country	US
Kind code	B2
Filing date	Sep 21, 2018
Priority date	Oct 31, 2011
Publication date	Nov 26, 2019
Grant date	Nov 26, 2019

Abstract

An apparatus is disclosed for identifying a fluid and locations of the fluid in a formation of shale having porous kerogen material and an inorganic matrix defining pores and micro-fractures. The apparatus includes: a carrier configured to be conveyed through a borehole penetrating the shale; a nuclear magnetic resonance (NMR) tool disposed at the carrier and configured to perform NMR measurements on the shale, the NMR measurements include a spectrum of transverse relaxation times; and a processor configured to receive NMR measurements on the shale performed by the NMR tool and to identify the fluid and locations of the fluid in the shale using the spectrum of transverse relaxation times.

First claim

What is claimed is:

1. A method for identifying a type of fluid and a state of the fluid in a formation of shale comprising an inorganic matrix defining pores and micro-fractures, the method comprising:
conveying a carrier through a borehole penetrating the formation of the shale;
performing nuclear magnetic resonance (NMR) measurements on the formation of shale using an NMR tool disposed at the carrier, the NMR measurements comprising a spectrum of transverse relaxation times; and
identifying the type of fluid and the state of the fluid in the formation of shale using the spectrum of transverse relaxation times.

2. The method according to claim 1 , wherein the formation of shale comprises kerogen pores.

3. The method according to claim 2 , wherein the fluid is hydrocarbon material in a liquid state disposed in the kerogen pores in the formation of shale.

4. The method according to claim 3 , wherein a dimension of the kerogen pores is about 80 nanometers.

5. The method according to claim 3 , wherein the spectrum of transverse relaxation times comprises a peak at less than ten milliseconds.

6. The method according to claim 1 , wherein identifying comprises identifying a location of the fluid in the formation of shale.

7. The method according to claim 1 , wherein identifying comprises correlating a peak of the spectrum to a type of the fluid and the state of the fluid in the formation of shale.

8. The method according to claim 7 , wherein identifying comprises correlating a peak of the spectrum to a location of the fluid in the formation of the shale.

9. The method according to claim 1 , wherein the fluid is hydrocarbon material in a liquid state disposed in the pores or micro-fractures of the inorganic matrix.

10. The method according to claim 9 , wherein a dimension of the micro-fracture is less than one micrometer.

11. The method according to claim 9 , wherein the spectrum of transverse relaxation times comprises a peak in a range of 20 to 200 milliseconds.

12. The method according to claim 1 , wherein the fluid is water in a liquid state disposed in the pores or micro-fractures of the inorganic matrix.

13. The method according to claim 12 , wherein the spectrum of transverse relaxation times comprises a peak at less than 3.3 milliseconds.

14. The method according to claim 1 , wherein a dimension of the pores of the inorganic matrix is about a dimension of grains in the inorganic matrix.

15. The method according to claim 1 , wherein the fluid is hydrocarbon material in a liquid state disposed in the pores or micro-fractures of the inorganic matrix.

16. The method according to claim 15 , wherein a dimension of the pores of the inorganic matrix is less than two micrometers.

17. The method according to claim 15 , wherein the spectrum of transverse relaxation times comprises a peak at less than one second transverse relaxation time.

18. The method according to claim 1 , further comprising estimating a percentage of identified type of fluid by total volume of the shale by integrating the spectrum of transverse relaxation times over time.

19. The method according to claim 1 , wherein conveying a carrier comprises conveying one of a drill string, coiled tubing, and a wireline.

Assignees

• Chen Jinhong
• Zhang Jilin
• Jin Guodong
• Quinn Terrence
• Frost Jr Elton
• Baker Hughes A Ge Co Llc

Inventors

• Chen Jinhong
• Zhang Jilin
• Jin Guodong
• Quinn Terrence
• Frost Jr Elton

Classifications

• G01V3/32 Primary

  operating with electron or nuclear magnetic resonance · CPC title

• G01N24/081

  Making measurements of geologic samples, e.g. measurements of moisture, pH, porosity, permeability, tortuosity or viscosity · CPC title