Phase Behavior of Petroleum Reservoir Fluids

Pedersen, Karen Schou; Christensen, Peter Lindskou; Shaikh, Jawad Azeem

doi:10.1201/9781420018257

Cited by 347 publications

(341 citation statements)

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“…As a consequence, in the pursuit of the theoretical modelling of these mixtures, historically two schemes have become the mainstream tools of petroleum engineering; either the description as a continuum distribution 2 or the description as a discrete but finite set of pseudo-components 3 . Pseudocomponents are artificial assignments of a cut or fraction of the mixture to values of critical properties, densities and acentric factors which on average represent the bulk behaviour, obtained from measured oil bulk properties, light ends analysis, distillation, or other characterization methods.…”

Section: Introductionmentioning

confidence: 99%

Coarse grained force field for the molecular simulation of natural gases and condensates

Herdes

Totton

Müller

2015

Fluid Phase Equilibria

107

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A c c e p t e d M a n u s c r i p t Highlights -A framework to obtain accurate coarse-grained force fields is described -Force field parameters are presented for compounds of interest -A methodology to simulate bubble points of complex mixtures is proposed. -The force fields are shown to be robust and transferrable Highlights (for review) AbstractThe atomistically-detailed molecular modelling of petroleum fluids is challenging, amongst other aspects, due to the very diverse multicomponent and asymmetric nature of the mixtures in question. Complicating matters further, the time scales for many important processes can be much larger that the current and foreseeable capacity of modern computers running fully-atomistic models. To overcome these limitations, a coarse grained (CG) model is proposed where some of the less-important degrees of freedom are safely integrated out, leaving as key parameters the average energy levels, the molecular conformations and the range of the Mie intermolecular potentials employed as the basis of the model. The parametrization is performed by using an analytical equation of state of the statistical associating fluid theory (SAFT) family to link the potential parameters to macroscopically observed thermophysical properties. The parameters found through this top-down approach are used directly in molecular dynamics simulations of multi-component multi-phase systems. The procedure is exemplified by calculating the phase envelope of the methane-decane binary and of two synthetic light condensate mixtures. A procedure based on a discrete expansion of a mixture is used to determine the bubble points of these latter mixtures, with an excellent agreement to experimental data. The model presented is entirely predictive and an abridged table of parameters for some fluids of interest is provided.

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Section: Introductionmentioning

confidence: 99%

Coarse grained force field for the molecular simulation of natural gases and condensates

Herdes

Totton

Müller

2015

Fluid Phase Equilibria

107

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“…The modeling of multicomponent mixtures like reservoir fluids requires the availability of interaction parameters for every pair of components present in each particular fluid, at least as a reasonable default matrix from which then some values can be adjusted depending on the case, given that pseudo-components are actually used to describe real fluids (see for example [3]). …”

Section: Introductionmentioning

confidence: 99%

Modelling the phase behavior of alkane mixtures in wide ranges of conditions: New parameterization and predictive correlations of binary interactions for the RKPR EOS

Cismondi

Doblas²,

Gomez³

et al. 2015

Fluid Phase Equilibria

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“…The nonaqueous phase during this time period and for the specified fluid composition yields single-phase conditions above the phase envelope, indicating fully miscibility of the CO 2 with the reservoir fluid. A phase identification procedure proposed by Pedersen and Christensen [30] recommend identifying fluids with molar volume to cubic equation of state b-parameter ratio less than 1.75 as being liquid, and greater than 1.75 as being gas. To avoid flopping between liquid and gas within this region, the saturation transition function is implemented in STOMP-EOR for this single-phase region (i.e., above the phase envelope between the critical temperature and cricondentherm temperature in Fig.…”

Section: Tertiary Recovery Simulationmentioning

confidence: 99%

Numerical Simulation of Carbon Dioxide Injection in the Western Section of the Farnsworth Unit

et al. 2014

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Numerical simulation is an invaluable analytical tool for scientists and engineers in making predictions about of the fate of carbon dioxide injected into deep geologic formations for long-term storage. Current numerical simulators for assessing storage in deep saline formations have capabilities for modeling strongly coupled processes involving multifluid flow, heat transfer, chemistry, and rock mechanics in geologic media. Except for moderate pressure conditions, numerical simulators for deep saline formations only require the tracking of two immiscible phases and a limited number of phase components, beyond those comprising the geochemical reactive system. The requirements for numerically simulating the utilization and storage of carbon dioxide in partially depleted petroleum reservoirs are more numerous than those for deep saline formations. The minimum number of immiscible phases increases to three, the number of phase components may easily increase fourfold, and the coupled processes of heat transfer, geochemistry, and geomechanics remain. Public and scientific confidence in the ability of numerical simulators used for carbon dioxide sequestration in deep saline formations has advanced via a natural progression of the simulators being proven against benchmark problems, code comparisons, laboratory-scale experiments, pilot-scale injections, and commercial-scale injections. This paper describes a new numerical simulator for the scientific investigation of carbon dioxide utilization and storage in partially depleted petroleum reservoirs, with an emphasis on its unique features for scientific investigations. The mathematical foundations of this new simulator for enhanced oil recovery are those of the simulators developed for carbon sequestration in deep saline reservoirs, altered to consider the increased number of potential phases and compositional aspects by considering the oil in the system. As a demonstration of the simulator, a numerical simulation of carbon dioxide utilization for enhanced oil recovery in the western section of the Farnsworth Unit, representing an early stage in the progression of numerical simulators for carbon utilization and storage in depleted oil reservoirs.

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Phase Behavior of Petroleum Reservoir Fluids

Cited by 347 publications

References 0 publications

Coarse grained force field for the molecular simulation of natural gases and condensates

Coarse grained force field for the molecular simulation of natural gases and condensates

Modelling the phase behavior of alkane mixtures in wide ranges of conditions: New parameterization and predictive correlations of binary interactions for the RKPR EOS

Numerical Simulation of Carbon Dioxide Injection in the Western Section of the Farnsworth Unit

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