3D Images of residual oil in an Ottawa sand

Congjiao Xie, Saif Ai-Sayari and Martin BluntEarth Science and Engineering, Imperial College London

Outline• Aims• Overview • Experimental set-up

– The Hassler cell for Benchmark experiments– Apparatus for tiny samples– Micro-CT

• Results– 2D image– 3D first results

• Future Work• Acknowledgements

Aims

• To set up a new apparatus to image fluid distribution at the pore scale using micro-CT

• To gain a 3D image of the flow behavior at pore scale when brine, oil and gels are used

• To find the distribution of residual oil after the flow of water and cross-linked polyacrylamide

Overview•Reservoir engineering methods•Numerical Simulation•Micro-scale tests

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H K 30C

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H K 20B

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H K 11D 265

H K 12 D 762

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H K 100 250 500 750 1000

Procedure

Micro-CT imaging

Tiny Core Plug

Pores throats

coordination numbers

Fluidcharacterization

Actualnetwork

LatticeBoltzmann

Geometry

Network geometry

Element permeabilities

Fluids parameters

Core prediction

Permeabilities

Fluid parameters

Fluids injection

Experimental set-upHassler cell

Experimental set-upApparatus for tiny samples

PVC-U ( Polyvinyl Chloride )max operating temperatureis 60 ℃

37.8mm25.4mm6.5 mm

Experimental set-upApparatus for tiny sample

Injection sequence:

30 PV of oil

70 PV of brine

10 PV of Gel (HPAM)

(a low molecular weight and

low hydrolysis polyacrylamide

cross-linked with chromium)

20 PV of oil

3 PV of brine

Experimental set-upProperties of fluids

FluidsDensity

@20℃(gm/cm3)

Viscosity @20℃(mPa.s)

Brine

(5% Nacl + 1% Kcl)1.03 1.08

Oil

( Multipar H)0.76 1.13

HPAM Gel

(Tetramethoxysilane) 0.86 4.22

Experimental set-upApparatus for tiny sample

A range of rates from 0.5 to 50 cc/min

Experimental set-upMicro-CT scanner

ResultsPorosityPermeabilityRelative permeability

Ø=26.4%,K=200.8md Ø=23.4%,K=133md

Sw=44%Sw=50%

Sor=27% Sor=30%

ResultsNo. Date Porosity Permeability

1 13-09-06 32.3% 2.12D

2 20-10-06 34.8% 2.41D

3 23-11-06 33.1% 2.28D

No. Date Porosity Permeability

1 28-10-06 34.1% 2.01D

2 18-11-06 36.8% 2.25D

3 20-12-06 35.5% 2.13D

D=37.8 mm

D=6.6 mm

A subregion in Sw (b) The same region in Sor (c) pore/rock and brine/oil segmentation results for this regionFrom M.Prodanovic et al.2006

Results2D image

Results3D first results

Micro-CT data

Petrel Software

Modelling

3D image

Future Works

• Injecting Gel to simulate Polymer Drive Mechanism

• Injecting nitrogen and water to study three-phase flow

• Comparison of Micro-CT results with Benchmark experimental data on sand packs and sandstones

Residual oil distribution after

cross-linked polymer floodin

g at different steps

in Xiaermen oil field, China

a

c

b

grain

grain

grain

Residual oil distribution for different sandstone modelsFrom Xiaermen oil field, China

Crosslinkedpolymer

Residual oil after polyme

r flooding

crosslinkedpolymer

extendedresidual oil

skeleton

Future Works

• Distribution of residual oil saturation as a function of wettability and saturation history

Acknowledgements• I would like to express my sincere thanks t

o my supervisor Prof.Martin Blunt for his guidance and support throughout this work.

• I’m also grateful to Dr. Mariela for her initial discussions.

• I’d like to thank the administration of Petrophysics lab engineers for their helps.

• I’m also grateful to the staff for their friendly environment.

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