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Research Papers: Petroleum Engineering

Scaling Analysis and Modeling of Immiscible Forced Gravity Drainage Process

[+] Author and Article Information
Mohammad Mahdi Moshir Farahi

Institute of Petroleum Engineering,
School of Chemical Engineering,
College of Engineering,
University of Tehran,
PO Box 11365-4563
Tehran, Iran
e-mail: moshir.farahi@ut.ac.ir

Mohammad Reza Rasaei

Institute of Petroleum Engineering,
School of Chemical Engineering,
College of Engineering,
University of Tehran,
PO Box 11365-4563
Tehran, Iran
e-mail: mrasaei@ut.ac.ir

Behzad Rostami

Institute of Petroleum Engineering,
School of Chemical Engineering,
College of Engineering,
University of Tehran,
PO Box 11365-4563
Tehran, Iran
e-mail: brostmi@ut.ac.ir

Mostafa Alizadeh

Faculty of Chemical Engineering,
Tarbiat Modarres University,
P.O. Box 14115-114.
Tehran, Iran
e-mail: mostafa.alizadeh@modares.ac.ir

1Corresponding author.

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received January 14, 2013; final manuscript received November 20, 2013; published online January 15, 2014. Assoc. Editor: Hong-Quan (Holden) Zhang.

J. Energy Resour. Technol 136(2), 022901 (Jan 15, 2014) (8 pages) Paper No: JERT-13-1019; doi: 10.1115/1.4026093 History: Received January 14, 2013; Revised November 20, 2013

Scaling study of fluids displacement leads to proper understanding of pore-to-field scale flow mechanisms and correct evaluation of effectiveness of various recovery methods. Scaling study of immiscible forced gravity drainage, or gas assisted gravity drainage (GAGD), at laboratory scale and reservoir scale is considered here. Inspectional analysis (IA) is used to determine dimensionless scaling groups that characterize the fluid displacement and production mechanisms. It is found that scaling immiscible GAGD displacement in a homogeneous reservoir needs matching of five dimensionless scaling groups. For heterogeneous reservoirs, Dykstra-Parson coefficient which represents the permeability heterogeneity is also required. It is shown that none of the dimensionless groups can individually correlate the efficiency of the process. Hence, a new combined dimensionless group in reservoir scale which incorporates all the dominant forces is derived. The model is evaluated and verified by comparing its predictions with experimental results and extensive field simulations figures. The model is found reliable for fast oil recovery prediction of GAGD process after 2 pore volume injection in homogeneous and heterogeneous reservoirs and proposing their optimal production plan.

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References

Figures

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Fig. 1

Recovery factor after two pore volumes injected as a function of capillary number [16]

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Fig. 2

Recovery factor after two pore volumes injected as a function of bond number [16]

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Fig. 3

Recovery factor after two pore volumes injected as a function of combined number propose by Rostami et al. [16]

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Fig. 4

Recovery factor after two pore volumes injected as a function of gravity drainage number propose by Kulkarni and Rao [5]

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Fig. 5

Recovery factor of immiscible GAGD experiments by Rostami et al. [16] after 2PV injection as a function of newly proposed combined number

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Fig. 6

Schematic of the synthetic reservoir in which the GAGD process has been simulated

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Fig. 7

GAGD simulation results in homogeneous reservoirs after 2PV injection

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Fig. 8

Simulation results of recovery factor after 2PV injected as a function of newly modified combined number in field scale, homogeneous case

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Fig. 10

3D permeability map used in simulations; Kavg = 10 md, VDP = 0.52

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Fig. 9

2D permeability map used in simulations; Kavg = 10 md, VDP = 0.52

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Fig. 11

Simulation results of recovery factor after 2PV injected as a function of newly derived combined number in field scale for heterogeneous reservoirs

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