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Technical Brief

Evaluation of Explicit Coupling Between Reservoir Simulators and Production System

[+] Author and Article Information
João Carlos von Hohendorff Filho

Departamento de Engenharia de Petróleo,
Faculdade de Engenharia Mecânica,
UNICAMP,
Caixa Postal 6052, Campinas,
São Paulo CEP 13083-970, Brazil
e-mail: hohendorff@cepetro.unicamp.br

Denis José Schiozer

Departamento de Engenharia de Petróleo,
Faculdade de Engenharia Mecânica,
UNICAMP,
Caixa Postal 6052, Campinas,
São Paulo CEP 13083-970, Brazil
e-mail: denis@dep.fem.unicamp.br

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received September 19, 2013; final manuscript received October 17, 2014; published online November 6, 2014. Assoc. Editor: Andrew K. Wojtanowicz.

J. Energy Resour. Technol 136(4), 044501 (Nov 06, 2014) (5 pages) Paper No: JERT-13-1267; doi: 10.1115/1.4028860 History: Received September 19, 2013; Revised October 17, 2014

In recent years, the oil industry has used various methodologies to solve numerical coupling of reservoirs and production systems to properly model complex projects needing an integrated solution of computational models that represent the fluid flow through the reservoir up to the surface. We present a study of explicit coupling methodology testing the production system on common operating conditions, verifying the benefits and quantifying limitations of explicit methodology, due to numerical stability errors reported in literature.

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References

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Figures

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Fig. 1

Explicit coupling between reservoir simulator and production system simulator methodology flowchart

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Fig. 2

Tridimensional horizontal permeability (mD) of case 4––Namorado Field

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Fig. 3

Injected water rate and well bottom-hole pressure for IV-001 injector (case 1)

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Fig. 4

Well bottom-hole pressure for PV-001 and PV-003 producers (case 1)

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Fig. 5

Oil rate for PV-001 and PV-003 producers (case 2)

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Fig. 6

Injected water rate and well bottom-hole pressure for IV-001 injector (case 2)

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Fig. 7

Oil rate for PV-001 and PV-003 producers (case 3)

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Fig. 8

Liquid production and water injection from field (case 4)

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Fig. 9

Oil and water production from field (case 4)

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