Novel approach to core sample MCT research for practical petrophysics problems solution

UDK: 550.822.3
Key words: X-ray micro computed tomography, porosity, permeability, virtual cubes
Authors: I.V. Yazynina, E.V. Shelyago, A.A. Abrosimov Gubkin Russian State University of Oil and Gas (National Research University), RF, Moscow), O.N. Veremko (LUKOIL-Engineering LLC, RF, Moscow), E.A. Grachev, N.E. Grachev, D.A. Bikulov, D.S. Senin (Lomonosov Moscow State University, RF, Moscow)

X-ray micro computed tomography (MCT) is a modern method of porous bodies studying. MCT is associated with its ability to visualize structure of the reservoir rock cavities, as well as fluid flow numerical simulation. Many issues of MCT data processing and hydrodynamic modeling are debatable today. In publications available, authors usually focus on pores visualization, but single-phase and especially two-phase flow calculation occurs much less frequently. Researchers often use model objects; face with insufficient MCT resolution problem, limitations of mathematical algorithms and computing resources.

This paper is devoted to the development of a new, affordable approach to MCT research of oil and gas formation core material, aimed at calculating accurate reservoir properties of common Russian reservoir rocks. One of the novel approach ideas is virtual cutting of several porous media segment (virtual cubes) from each of three-dimensional models obtained via MCT. Paired values of porosity and permeability are calculated for each cube. Group of cubes cut from the same model, generates a point cloud. Strong heterogeneity of reservoir properties at the pore level allows covering larger range of values. Finally, it is possible to get not one, but several pairs of porosity and permeability values from each MCT-shooting, which allows saving microtomograph system resource. Such an approach can find practical application in petrophysics when dealing with poorly consolidated rocks, unsuitable for traditional methods of reservoir properties measurement, and little collections of core material. 

   References

1. URL: http://www.ostec-x-ray.ru/areas-of-application/oil-and-gas/parametri-

opredelyaemie-iz-tomograficheskikh-dannikh-kerna/

2. Chugunov S.S., Kazak A.V., Cheremisin A.N., Integration of X-ray microcomputed

tomography and focused-ion-beam scanning electron microscopy

data for pore-scale characterization of Bazhenov formation, Western

Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 10,

pp. 44-49.

3. Wildenschild D., Sheppard A.P., X-ray imaging and analysis techniques for

quantifying pore-scale structure and processes in subsurface porous medium

systems, Advances in Water Resources.7, 2012.

4. Korost D.V., Gerke K.M., Computation of reservoir properties based on 3Dstructure

of porous media (In Russ.), SPE-162023-RU, 2012.

5. Dinariev O.Yu., Mikhaylov D.N., Modelirovanie dinamicheskoy (chastotnozavisimoy)

pronitsaemosti i elektroprovodnosti v poristykh materialakh na osnove

kontseptsii ansamblya por (In Russ.), Prikladnaya mekhanika i tekhnicheskaya

fizika, 2011, V. 52, no. 1, pp. 101-118.

6. Grader A.S., Clark A.B.S., Al-Dayyani T., Nur A., Computations of porosity

and permeability of sparic carbonate using multi-scale CT images, Proceedings

of International Symposium of the Society of Core Analysts, Noordwijk,

The Netherlands, 27-30 September, 2009.

7. Sok R.M., Varslot T., Ghous A., Latham S., Sheppard A.P., Knackstedt M.A.,

Pore scale characterization of carbonates at multiple scales: integration of

micro-CT, BSEM and FIBSEM, Proceedings of International Symposium of the

Society of Core Analysts, Noordwijk, The Netherlands, 27-30 September, 2009.

8. Zakirov T.R., Galeev A.A., Konovalov A.A., Statsenko E.O., Analysis of the

''representative elementary volume'' sandstones reservoir properties using the

method of X-ray computed tomography in Ashalchinskoye oil field (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2015, no. 10, pp. 54-57.

9. Culligan K.A., Wildenschild D., Chris tensen B.S.B., Gray W.G., Rivers M.L.,

Tompson A.F.B., Interfacial area measurements for unsaturated flow through

a porous medium, Water resources research, 2004, no. 40, рр. 1–12.

10. Silin D., Tomutsa L., Benson S.M., Padzek T.W., Microtomography and porescale

modeling of two-phase fluid distribution, Transport in Porous Media,

2011, V. 86, pp. 495-515, doi: 10.1007/s11242-010-9636-2.

11. Brusseau M.L., Peng S., Schnaar G., Costanza-Robinson M.S., Relationships

among air-water interfacial area, capillary pressure, and water saturation for

a sandy porous medium, Water resources research, 2006, no. 42, рр. 1–5.

12. Dvorkin J., Derzhi N., Fang Q., Nur A., Nur B., Grader A., Baldwin C., Tono H.,

Diaz E., From micro to reservoir scale: Permeability from digital experiments,

The Leading Edge, 2009, no. 12, pp. 1446-1453.

X-ray micro computed tomography (MCT) is a modern method of porous bodies studying. MCT is associated with its ability to visualize structure of the reservoir rock cavities, as well as fluid flow numerical simulation. Many issues of MCT data processing and hydrodynamic modeling are debatable today. In publications available, authors usually focus on pores visualization, but single-phase and especially two-phase flow calculation occurs much less frequently. Researchers often use model objects; face with insufficient MCT resolution problem, limitations of mathematical algorithms and computing resources.

This paper is devoted to the development of a new, affordable approach to MCT research of oil and gas formation core material, aimed at calculating accurate reservoir properties of common Russian reservoir rocks. One of the novel approach ideas is virtual cutting of several porous media segment (virtual cubes) from each of three-dimensional models obtained via MCT. Paired values of porosity and permeability are calculated for each cube. Group of cubes cut from the same model, generates a point cloud. Strong heterogeneity of reservoir properties at the pore level allows covering larger range of values. Finally, it is possible to get not one, but several pairs of porosity and permeability values from each MCT-shooting, which allows saving microtomograph system resource. Such an approach can find practical application in petrophysics when dealing with poorly consolidated rocks, unsuitable for traditional methods of reservoir properties measurement, and little collections of core material. 

   References

1. URL: http://www.ostec-x-ray.ru/areas-of-application/oil-and-gas/parametri-

opredelyaemie-iz-tomograficheskikh-dannikh-kerna/

2. Chugunov S.S., Kazak A.V., Cheremisin A.N., Integration of X-ray microcomputed

tomography and focused-ion-beam scanning electron microscopy

data for pore-scale characterization of Bazhenov formation, Western

Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 10,

pp. 44-49.

3. Wildenschild D., Sheppard A.P., X-ray imaging and analysis techniques for

quantifying pore-scale structure and processes in subsurface porous medium

systems, Advances in Water Resources.7, 2012.

4. Korost D.V., Gerke K.M., Computation of reservoir properties based on 3Dstructure

of porous media (In Russ.), SPE-162023-RU, 2012.

5. Dinariev O.Yu., Mikhaylov D.N., Modelirovanie dinamicheskoy (chastotnozavisimoy)

pronitsaemosti i elektroprovodnosti v poristykh materialakh na osnove

kontseptsii ansamblya por (In Russ.), Prikladnaya mekhanika i tekhnicheskaya

fizika, 2011, V. 52, no. 1, pp. 101-118.

6. Grader A.S., Clark A.B.S., Al-Dayyani T., Nur A., Computations of porosity

and permeability of sparic carbonate using multi-scale CT images, Proceedings

of International Symposium of the Society of Core Analysts, Noordwijk,

The Netherlands, 27-30 September, 2009.

7. Sok R.M., Varslot T., Ghous A., Latham S., Sheppard A.P., Knackstedt M.A.,

Pore scale characterization of carbonates at multiple scales: integration of

micro-CT, BSEM and FIBSEM, Proceedings of International Symposium of the

Society of Core Analysts, Noordwijk, The Netherlands, 27-30 September, 2009.

8. Zakirov T.R., Galeev A.A., Konovalov A.A., Statsenko E.O., Analysis of the

''representative elementary volume'' sandstones reservoir properties using the

method of X-ray computed tomography in Ashalchinskoye oil field (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2015, no. 10, pp. 54-57.

9. Culligan K.A., Wildenschild D., Chris tensen B.S.B., Gray W.G., Rivers M.L.,

Tompson A.F.B., Interfacial area measurements for unsaturated flow through

a porous medium, Water resources research, 2004, no. 40, рр. 1–12.

10. Silin D., Tomutsa L., Benson S.M., Padzek T.W., Microtomography and porescale

modeling of two-phase fluid distribution, Transport in Porous Media,

2011, V. 86, pp. 495-515, doi: 10.1007/s11242-010-9636-2.

11. Brusseau M.L., Peng S., Schnaar G., Costanza-Robinson M.S., Relationships

among air-water interfacial area, capillary pressure, and water saturation for

a sandy porous medium, Water resources research, 2006, no. 42, рр. 1–5.

12. Dvorkin J., Derzhi N., Fang Q., Nur A., Nur B., Grader A., Baldwin C., Tono H.,

Diaz E., From micro to reservoir scale: Permeability from digital experiments,

The Leading Edge, 2009, no. 12, pp. 1446-1453.



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