Porous micromodel network to simulate formation flows

Patent metadata

Field	Value
Publication number	US-2020333230-A1
Application number	US-201916386897-A
Country	US
Kind code	A1
Filing date	Apr 17, 2019
Priority date	Apr 17, 2019
Publication date	Oct 22, 2020
Grant date	—

Abstract

A porous micromodel network to simulate formation flows includes a substrate, two or more porous micromodels formed on the substrate and a fluid inlet formed on the substrate. The first porous micromodel defines a first fluidic flow pathway and is representative of a first hydrocarbon-carrying formation. Flow through the first fluidic flow pathway is representative of flow through the first hydrocarbon-carrying formation. The second porous micromodel is fluidically isolated from the first porous micromodel. The second porous micromodel defines a second fluidic flow pathway different from the first fluidic flow pathway. The second porous micromodel is representative of a second hydrocarbon-carrying formation different from the first hydrocarbon-carrying formation. Flow through the second fluidic flow pathway is representative of flow through the second hydrocarbon-carrying formation. The fluid inlet is fluidically configured to simultaneously flow fluid to the first fluidic flow pathway and the second fluidic flow pathway.

First claim

1 . An apparatus comprising:
a substrate; a first porous micromodel formed on the substrate, the first porous micromodel defining a first fluidic flow pathway, the first porous micromodel representative of a first hydrocarbon-carrying formation, flow through the first fluidic flow pathway representative of flow through the first hydrocarbon-carrying formation; a second porous micromodel formed on the substrate, the second porous micromodel fluidically isolated from the first porous micromodel, the second porous micromodel defining a second fluidic flow pathway different from the first fluidic flow pathway, the second porous micromodel representative of a second hydrocarbon-carrying formation different from the first hydrocarbon-carrying formation, flow through the second fluidic flow pathway representative of flow through the second hydrocarbon-carrying formation; and a fluid inlet formed on the substrate, the fluid inlet fluidically configured to simultaneously flow fluid to the first fluidic flow pathway and the second fluidic flow pathway.

2 . The apparatus of claim 1 , wherein the first hydrocarbon-carrying formation is an ideal hydrocarbon-carrying formation, the first porous micromodel comprises first porous media defining a first plurality of pores that defines the first fluidic flow pathway, the first plurality of pores having substantially identical dimensions.

3 . The apparatus of claim 2 , wherein the first plurality of pores are substantially equidistantly spaced apart from each other.

4 . The apparatus of claim 3 , wherein each of the first plurality of pores is circular, wherein the first plurality of pores has substantially the same diameter.

5 . The apparatus of claim 1 , wherein the second hydrocarbon-carrying formation is an actual hydrocarbon-carrying formation, the second porous micromodel comprises second porous media defining a second plurality of pores that defines the second fluidic flow pathway, the second plurality of pores having a range of varying dimensions.

6 . The apparatus of claim 5 , wherein the second plurality of pores are spaced at varying distances from each other.

7 . The apparatus of claim 1 , further comprising:
a first porous micromodel fluid inlet formed on the substrate at an edge of the first porous micromodel, the first porous micromodel fluid inlet fluidically connected to the fluid inlet formed on the substrate, the first porous micromodel fluid inlet configured to receive fluid from the fluid inlet and to flow the fluid into the first fluidic pathway; and a second porous micromodel fluid inlet formed on the substrate at an edge of the second porous micromodel, the second porous micromodel fluid inlet fluidically connected to the fluid inlet formed on the substrate, the second porous micromodel fluid inlet configured to receive fluid from the fluid inlet and to flow the fluid into the second fluidic pathway.

8 . The apparatus of claim 7 , wherein the first porous micromodel fluid inlet and the second porous micromodel fluid inlet have the same dimensions.

9 . The apparatus of claim 7 , further comprising:
a first porous micromodel fluid outlet formed on the substrate at another edge of the first porous micromodel, the first porous micromodel fluid outlet configured to permit the fluid flowed through the first fluidic pathway to exit the first porous micromodel; and a second porous micromodel fluid outlet formed on the substrate at another edge of the second porous micromodel, the second porous micromodel fluid outlet configured to permit the fluid flowed through the second fluidic pathway to exit the second porous micromodel.

10 . The apparatus of claim 1 , wherein the substrate is made of silicon wafer, wherein the apparatus further comprises a transparent plate that fluidically seals the first porous micromodel and the second porous micromodel.

11 . The apparatus of claim 1 , further comprising a wall between the first porous micromodel and the second porous micromodel, the wall fluidically isolating the first porous micromodel from the second porous micromodel.

12 . A laboratory-scale system comprising:
a porous micromodel network comprising a plurality of porous micromodels that are different from each other and that are fluidically isolated from each other, each porous micromodel defining a respective fluidic flow pathway, each porous micromodel representative of a respective hydrocarbon-carrying formation, flow through the each fluidic flow pathway representative of flow through the respective hydrocarbon-carrying formation; and a fluid flow device configured to simultaneously flow fluid through the porous micromodel network.

13 . The system of claim 12 , further comprising a flow manifold comprising an inlet fluidically coupled to the fluid flow device and a plurality of outlets, one outlet per porous micromodel, the plurality of outlets fluidically coupled to a respective plurality of porous micromodel inlets, the flow manifold configured to receive fluid from the fluid flow device and simultaneously flow the fluid to the porous micromodel network.

14 . The system of claim 12 , further comprising a plurality of pressure gauges, one pressure gauge per porous micromodel, the plurality of pressure gauges coupled to the respective plurality of porous micromodels, each pressure gauge configured to measure a flow pressure of the fluid through the respective porous micromodel.

15 . The system of claim 12 , further comprising a flow visualization device spatially positioned relative to the porous micromodel network, the flow visualization device configured to capture flow and saturation of the fluid through each porous micromodel.

16 . The system of claim 15 , wherein the flow visualization device comprises a camera.

17 . The system of claim 16 , wherein the flow visualization device comprises a microscope coupled to the camera.

18 . The system of claim 12 , wherein the fluid flow device comprises a pump configured to pump the fluid through the porous micromodel network.

19 . The system of claim 18 , further comprising a plurality of fluid containers, each fluid container carrying a hydrocarbon-carrying formation fluid, the pump configured to draw the hydrocarbon-carrying formation fluid from one of the plurality of fluid containers and flow the hydrocarbon-carrying formation fluid simultaneously through the porous micromodel network.

20 . A method comprising:
simultaneously flowing a plurality of fluids through a respective, plurality of laboratory-scale porous micromodels of a porous micromodel network, the plurality of porous micromodels fluidically isolated from each other, each porous micromodel defining a respective fluidic flow pathway, each porous micromodel representative of a respective hydrocarbon-carrying formation, flow through the each fluidic flow pathway representative of flow through the respective hydrocarbon-carrying formation; imaging flow of the plurality of fluids through the respective, plurality of porous micromodels; and evaluating flow through each respective hydrocarbon-carrying formation based on imaging the flow and the saturation of the fluid.

21 . The method of claim 20 , wherein the plurality of laboratory-scale micromodels comprises two porous micromodels and the plurality of fluids comprises two same fluids.

22 . The method of claim 20 , wherein the plurality of laboratory-scale micromodels are different from each other.

Assignees

• Saudi Arabian Oil Co

Inventors

• Almaskeen Lyla
• Alshehri Amar Jaber M

Classifications

• G09B23/40

  for geology · CPC title

• G01N11/08 Primary

  by measuring pressure required to produce a known flow · CPC title

• G01N7/00

  Analysing materials by measuring the pressure or volume of a gas or vapour · CPC title

• G01V1/3808

  Seismic data acquisition, e.g. survey design · CPC title

• E21B49/00 Primary

  Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells · CPC title