Trends in Reservoir Simulation: Big Models, Scalable Models? Will you Please Make up Your Mind?

Gorell, Sheldon; Bassett, Robert

doi:10.2523/71596-ms

Cited by 5 publications

(5 citation statements)

References 6 publications

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“…The composition of the surface oil (x H G , x I G ) resulting from the separation of the reservoir gas can be computed from its molar mass, by writing molar mass conservation: (1) and closure equation: (2) Symbols are defined in the nomenclature. Applying the same rules to the four surface phases resulting from the separation of both reservoir gas and oil phases, one gets the following subset of equations: The compositions of the reservoir phases are then obtained by recombination of their respective surface oil and gas phases: The former derivations show that setting the three component molar masses allows for a determination of the ternary compositions of both oil and gas phases at each thermodynamic equilibrium step of the PVT simulations, using simply the surface separation results in terms of phase molecular weight, and vapor fraction.…”

Section: 'Brown Oil' Model Building the Ternary Representationmentioning

confidence: 99%

From BO (Binary) to Ternary Fluid Representation for Simulation of Condensate Recovery by Lean Gas Injection

BARROUX¹

2003

Proceedings of SPE Asia Pacific Oil and Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractFor the simulation of condensate recovery by lean gas injection below the gas dew point, a common statement is that most of the Black-Oil approaches are not reliable, and that typically 6 to 8 pseudo components in a compositional simulation model are needed, the draw back being a much more considerable computation time.A novel approach, inspired in some extent from BO modeling, has been found adequate to simulate the vaporization effects in the reservoir as lean gas is injected below the dew point. This approach uses a three-component representation of the reservoir fluid. A special attention has been devoted to establish a methodology of practical use for generating the PVT data. To recover the detailed compositional information lost by the use of pseudo components for the dynamic computations, a methodology for delumping the results of the simulation has also been considered.The paper presents firstly the bases of the lumping procedure used for building the ternary representation, the methodology for generating the PVT data, and considerations for delumping the simulation results. Then, test examples are provided, with a comparison between the simulation results obtained with the ternary representation, and with the reference (detailed) compositional representation. Results are shown to be in good agreement, while considerable CPU reduction factors are obtained.

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Section: 'Brown Oil' Model Building the Ternary Representationmentioning

confidence: 99%

From BO (Binary) to Ternary Fluid Representation for Simulation of Condensate Recovery by Lean Gas Injection

BARROUX¹

2003

Proceedings of SPE Asia Pacific Oil and Gas Conference and Exhibition

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“…It is well known that subsurface appears to be heterogeneous from nm to km scales [5]. That feature can lead engineers to build over parameterized numerical models that are used to help decision making on the field [6,7]: well implantation, injection or recovery strategy, uncertainty management etc. .…”

Section: Introductionmentioning

confidence: 99%

Statistical physics and applied geosciences: some results and perspectives

Nœtinger¹

2021

Comptes Rendus. Physique

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“…Christensen et al presented a comprehensive literature of the WAG processes in about 59 fields and commented on several severe problems which caused the decrease in displacement efficiency when performing WAG-CO 2 injection. The fundamental challenges with WAG injection are the water and gas breakthrough and decrease in infectivity (Christensen et al 1998;Gorell et al 2001) due to challenges such as viscous variabilities/ fingering, gravity separation, through high permeability streaks zone.…”

Section: Introductionmentioning

confidence: 99%

Formation of Anhydrite Due to Interaction Between Water Soluble CO2(aq) and Calcite Mineral During Enhanced Oil Recovery

Chakravarty¹,

Thomsen

2015

All Days

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In the Low Salinity based EOR method, formation and migration of fines have proved to have profound effect on the displacement efficiency of residual oil. Salinity variations of injected brines have also been shown to affect oil recovery for WAG-CO 2 processes. But the effect of fines in EOR during LSWAG-CO 2 has not been previously studied. This study explores the possibility of fines formation during CO 2 injection and attempts to understand its implication in EOR.In this study we use the Extended UNIQUAC model to calculate the possibility of fines formation during CO 2 injection. Detailed simulations were conducted over a temperature range of 50°C to 250°C and a pressure range of 5 bars to 500 bars. The amounts of fines formation taking place for different LSWAG-CO 2 processes were correlated to the described oil recovery. It is observed that significant amounts of fines formation can take place during CO 2 injection in limestone reservoirs. At reservoir conditions, a considerable fraction of the injected CO 2 becomes soluble in sea water. This dissolved CO 2 causes dissolution of CaCO 3 from the mineral surface and releases Ca 2ϩ ions into the pore space. Excess Ca 2ϩ ions form anhydrite fines with the available SO 4 2ions. The salinity and composition of brines present in pore space shows direct correlation with the amount of fines produced during CO 2 injection. With increase in temperature and pressure, the amount fines formation increased significantly.The described oil recovery for different LSWAG injections showed a consistent correlation with the amounts of fines formation taking place in the pore space. The amount of mineral dissolution taking place was also precisely calculated using the Extended UNIQUAC model. Good correlation was also observed between calculated amounts of mineral dissolution and the observed increase in permeability. This study suggests that CO 2 injection in carbonate reservoir can have two distinct effects.1. CO 2 miscible with oil can decrease oil viscosity, thus increase oil displacement. 2. CO 2 dissolved in water causes fines formation following dissolution of CaCO 3 . These fines can alter sweep efficiency by blocking pore throats and also increase oil displacement through its emulsification.Injection of CO 2 leads to fines formation at most reservoir conditions. These anhydrite fines formations have been neglected in previous studies. The amount of fines formation taking place shows significant correlation to EOR obtained from LSWAG injection. The Extended UNIQUAC model can be used to precisely calculate both the amount of mineral dissolution and the amounts of fines formation taking place during CO 2 injection over varied pressure and temperature conditions.

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Trends in Reservoir Simulation: Big Models, Scalable Models? Will you Please Make up Your Mind?

Cited by 5 publications

References 6 publications

From BO (Binary) to Ternary Fluid Representation for Simulation of Condensate Recovery by Lean Gas Injection

From BO (Binary) to Ternary Fluid Representation for Simulation of Condensate Recovery by Lean Gas Injection

Statistical physics and applied geosciences: some results and perspectives

Formation of Anhydrite Due to Interaction Between Water Soluble CO2(aq) and Calcite Mineral During Enhanced Oil Recovery

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