Nuclear magnetic resonance gas isotherm technique to evaluate reservoir rock wettability

Patent metadata

Field	Value
Publication number	US-9599581-B2
Application number	US-201615069650-A
Country	US
Kind code	B2
Filing date	Mar 14, 2016
Priority date	Apr 22, 2015
Publication date	Mar 21, 2017
Grant date	Mar 21, 2017

Abstract

Nuclear magnetic resonance (NMR) gas isotherm techniques to evaluate wettability of porous media, such as hydrocarbon reservoir rock, can include constructing a NMR gas isotherm curve for a porous media sample gas adsorption under various pressures. A hydrophobic or hydrophilic nature of the porous media sample can be determined using the NMR gas isotherm curves. A wettability of the porous media sample can be determined based on the NMR gas isotherm curve. The wettability can be determined for porous media samples with different pore sizes. In the case of reservoir rock samples, the determined wettability can be used, among other things, to model the hydrocarbon reservoir that includes such rock samples, to simulate fluid flow through such reservoirs, or to model enhanced hydrocarbon recovery from such reservoirs.

First claim

The invention claimed is:

1. A method comprising:
applying a plurality of pressures to a three-dimensional reservoir rock sample in a closed volume, the reservoir rock sample comprising a plurality of porous regions distributed along a longitudinal axis of the reservoir rock sample, wherein the plurality of porous regions have a respective plurality of wettabilities, each wettability representing a quality of each porous region to absorb water;
at each pressure of the plurality of pressures, applying a spin-echo single-point imaging (SE-SPI) pulse sequence to the plurality of porous regions distributed along the longitudinal axis of the reservoir rock sample;
constructing a nuclear magnetic resonance (NMR) gas isotherm curve for the reservoir rock sample in response to applying the plurality of pressures and, at each pressure of the plurality of pressures, applying the SE-SPI pulse sequence to the plurality of porous regions distributed along the longitudinal axis of the reservoir rock sample;
determining the plurality of wettabilities for the plurality of porous regions based on the NMR gas isotherm curve, each wettability of the plurality of wettabilities including a value representing the quality of each porous region to absorb water;
determining a spatial wettability distribution for the reservoir rock sample based on the plurality of wettabilities; and
providing the spatial wettability distribution for the reservoir rock sample.

2. The method of claim 1 , wherein the NMR gas adsorption isotherm curve comprises an NMR water vapor adsorption isotherm curve.

3. The method of claim 1 , further comprising:
determining that the NMR gas isotherm curve is a convex curve; and
determining that the reservoir rock sample comprises more hydrophilic surfaces than hydrophobic surfaces.

4. The method of claim 1 , further comprising:
determining that the NMR gas isotherm curve is a concave curve; and
determining that the reservoir rock sample comprises more hydrophobic surfaces than hydrophilic surfaces.

5. The method of claim 1 , wherein determining the spatial wettability of the reservoir rock sample comprises determining the spatial wettability based on whether the reservoir rock sample comprises more hydrophilic surfaces or more hydrophobic surfaces.

6. The method of claim 1 , wherein a porosity of the plurality of porous regions ranges between less than a micrometer and greater than a micrometer, and wherein determining the spatial wettability of the rock sample comprises:
determining a first wettability of a first porous region of the reservoir rock sample having a porosity less than a micrometer; and
determining a second wettability of a second porous region of the reservoir rock sample having a porosity greater than or equal to a micrometer.

7. The method of claim 1 , wherein determining the plurality of wettabilities for the plurality of porous regions based on the NMR gas isotherm curve, each wettability of the plurality of wettabilities including a value representing the quality of each porous region to absorb water comprises: comparing the NMR gas isotherm curve for the reservoir rock sample gas adsorption with a first standard NMR gas isotherm curve for a hydrophobic sample and a second standard NMR gas isotherm curve for a hydrophilic sample.

8. The method of claim 7 , further comprising:
constructing a nuclear magnetic resonance (NMR) gas isotherm curve for the hydrophobic sample; and
constructing a nuclear magnetic resonance (NMR) gas isotherm curve for the hydrophilic sample.

9. The method of claim 8 , wherein the hydrophobic sample comprises beads coated with a hydrophobic coating, and wherein the hydrophilic sample comprises beads coated with a hydrophilic coating.

10. The method of claim 1 , wherein determining the plurality of wettabilities for the plurality of porous regions based on the NMR gas isotherm curve, each wettability of the plurality of wettabilities including a value representing the quality of each porous region to absorb water comprises:
determining a first quantitative value for a first porous region having a porosity ranging less than a micrometer; and
determining a second quantitative value for a second porous region having a porosity ranging greater than or equal to a micrometer.

11. The method of claim 10 , wherein determining the first quantitative value comprises determining a normalized area under the NMR gas isotherm curve for the first porous region.

12. The method of claim 11 , wherein determining the first quantitative value comprises determining that the reservoir rock sample is water wet in response to determining that the normalized area under the curve is between 0 and substantially 0.5, determining that the reservoir rock sample is intermediate wet in response to determining that the normalized area under the curve is substantially equal to 0.5, or determining that the reservoir rock sample is water wet in response to determining that the normalized area under the curve is between substantially 0.5 and 1.

13. The method of claim 11 , wherein determining the second quantitative value comprises determining a ratio of a difference between a water vapor adsorption amount of the reservoir rock sample and a water vapor adsorption amount of the hydrophobic sample and a difference between a water vapor adsorption amount of the hydrophilic sample and the water vapor adsorption amount of the hydrophobic sample.

14. The method of claim 13 , wherein determining the second quantitative value comprises determining that the reservoir rock sample is water wet in response to determining that the ratio is between 0 and substantially 0.5, determining that the reservoir rock sample is intermediate wet in response to determining that the ratio is substantially equal to 0.5, or determining that the reservoir rock sample is oil wet in response to determining that the ratio is between substantially 0.5 and 1.

15. The method of claim 11 , wherein determining the second quantitative value comprises determining a ratio between a water vapor adsorption of the reservoir rock sample and a water vapor adsorption of the hydrophilic sample.

16. The method of claim 1 , wherein, at each pressure of the plurality of pressures, applying a SE-SPI pulse sequence to the plurality of porous regions distributed along the longitudinal axis of the reservoir rock sample comprises, while applying each pressure:
applying the SE-SPI pulse sequence to the plurality of porous regions in the reservoir rock sample; and
for each porous region, measuring a T2 decay time responsive to the applied pressure.

17. A system comprising:
a nuclear magnetic resonance (NMR) sample cell configured to receive a reservoir rock sample comprising a plurality of porous regions distributed along a longitudinal axis of the reservoir rock sample, wherein the plurality of porous regions have a respective plurality of wettabilities, each wettability representing a quality of each porous region to absorb water;
a pressure delivery system connected to the NMR sample cell, the pressure delivery system configured to apply a plurality of pressures to the reservoir rock sample in the NMR sample cell;
a NMR control system connected to the NMR sample cell, the NMR control system configured to, at each pressure of the plurality of pressures, apply a spin-echo single-point imaging (SE-SPI) pulse sequence to the plurality of porous regions distributed along the longitudinal axis of the reservoir rock sample; and
a computer system connected to the NMR control system and the pressure delivery system, th

Assignees

• Saudi Arabian Oil Co

Inventors

• Kwak Hyung Tae
• Al-Harbi Ahmad Mubarak

Classifications

• G01R33/305 Primary

  specially adapted for high-pressure applications · CPC title

• G01N24/082

  Measurement of solid, liquid or gas content · CPC title

• G01N13/00 Primary

  Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects (scanning-probe techniques or apparatus G01Q) · CPC title

• G01R33/5617

  using RF refocusing, e.g. RARE · CPC title

• G01N11/00 Primary

  Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties · CPC title