Modelling of diffusional mass transfer in naturally fractured reservoirs

Riazi, M.R.; Whitson, Curtis Hays; Silva, Flávio da

doi:10.1016/0920-4105(94)90084-1

Cited by 25 publications

(13 citation statements)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Estimation of the diffusion coefficient ( D ) is important for many science and engineering applications. In petroleum engineering, this parameter is used to model and design oil recovery processes using gas injection . In particular, the diffusion coefficient allows the calculation of the transfer rate of gas diffusing through the bulk heavy oil.…”

Section: Introductionmentioning

confidence: 99%

Estimation of concentration‐dependent diffusion coefficients of gases in heavy oils/bitumen using experimental pressure‐decay data

Roman

Hejazi

2016

Can J Chem Eng

View full text Add to dashboard Cite

The diffusion coefficient (D) of gases in heavy oils is an important mass transfer parameter to model and design gas injection processes for oil recovery. The pressure‐decay technique (PDT) is one of the widely used experimental methods available to infer this coefficient. PDT records the declining gas phase pressure resulting from the diffusion of gas into heavy oil inside a pressure/volume/temperature (PVT) cell. Commonly, the gas phase pressure decay is modelled by use of Fick's second law along with gas‐phase mass balance equations and assuming a constant diffusion coefficient. In this work, we evaluate two concentration‐dependent diffusion coefficient functions, power‐law and exponential. A simple history matching technique is used to estimate the apparent diffusion coefficient (Do) and concentration dependency factor (ma) from pressure‐decay data. Extensive application of our method to experimental pressure‐decay tests shows that in addition to constant diffusion coefficients, both power‐law and exponential functions are capable of predicting the experimental data. This implies that other experimental techniques are required to extract the functionality of diffusion coefficients with gas concentrations in heavy oil.

show abstract

Section: Introductionmentioning

confidence: 99%

Estimation of concentration‐dependent diffusion coefficients of gases in heavy oils/bitumen using experimental pressure‐decay data

Roman

Hejazi

2016

Can J Chem Eng

View full text Add to dashboard Cite

show abstract

“…As heavy oil is highly viscous, solubility and diffusivity data are required to determine the rate and the amount of the solvent to be injected into a reservoir to achieve the desired heavy oil viscosity reduction . Phase behaviour studies can be employed as screening tools with which to evaluate the effectiveness of gaseous solvent applications with respect to enhancing the recovery, and properly designing a solvent‐based process.…”

Section: Introductionmentioning

confidence: 99%

Solubility Of CO₂ and C₂H₆ in heavy Oil and its Sara fractions

Marufuzzaman

Henni

2015

Can J Chem Eng

View full text Add to dashboard Cite

Solvent‐based recovery is one of the most promising techniques to enhance heavy oil/bitumen recovery as an alternative to thermal methods. Phase behaviour study of light gases in heavy oil is therefore very important when designing operation and surface facilities for heavy oil recovery. In this study, the original oil (Cactus Lake) was first characterized into saturate, aromatic, resin, asphaltene, and maltene fractions (0.0 wt. % asphaltene). An intelligent gravimetric microbalance was used to measure the solubility of carbon dioxide and ethane in the heavy oil and its saturate, aromatic, resin, asphaltene, and maltene fractions. The measurements were carried out at 288, 294, 299, and 303 K, and at pressures from 200 to 2000 kPa. The standard Peng‐Robinson equation of state was used to correlate the experimental results. The associated Henry's law constants were regressed and reported. The adsorbed amounts of carbon dioxide and ethane on asphaltene were correlated using the Freundlich isotherm. As for the given heavy oil sample and its fractions, carbon dioxide showed lower solubility than ethane at constant temperature, even at high pressures. It was observed that the asphaltene content affects ethane solubility quite significantly in this heavy oil when compared to carbon dioxide.

show abstract

“…Also, dissolving gas in oil causes the oil to expand and reduce its density, and thereby the oil exits from the rock. Moreover, when liquid and gas phases are not in equilibrium, one or more components move from one phase to another one due to molecular diffusion [4,11,[21][22][23][24]. The presence of dual porosity including porous media (low permeability/ high porosity) and fracture networks (high permeability/ low porosity) with different physical properties causes the structure of fractured reservoirs much more complex than conventional non-fractured reservoirs so that conventional methods which have been used for studying the performance of the reservoirs cannot present appropriate results to examine the behavior of reservoirs [10,14,25].…”

Section: Introductionmentioning

confidence: 99%

Numerical modeling of molecular diffusion and convection effects during gas injection into naturally fractured oil reservoirs

Gholamian

Ehsani

Nikookar

et al. 2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

View full text Add to dashboard Cite

Gas injection into a naturally fractured oil reservoir keeps the reservoir pressure and increments the initial recovery from the reservoir. The main aim of this work was to develop a numerical model to calculate the mass transfer (molecular diffusion and convection) between a gas injected in the fracture and residual fluid (gas and oil) in a matrix block. The dual continuum model is applied to describe flow behaviour and fluid recovery in porous media. Finally, the model is validated by comparing the outcomes with the results of two experimental works available in the literature. The mathematical model results are in agreement with the laboratory data including recovery of each component, saturation profile, and the pressure gradient between matrix and fracture. Modeling results show that after 25 days of N2 injection, the lighter and heavier components (C1 and C5) are recovered about 51% and 39%, respectively. These amounts for CO2 injection are 49% and 27%. It is found that the convection mechanism has a great effect on preventing the pressure drop of the reservoir during injection operations. In the nitrogen injection, without considering the convection, after 30 days, the matrix pressure reaches 1320 Psi from 1479 Psi but after 30 days, considering the convection, the pressure reaches 1473 Psi from 1479 Psi.

show abstract

Modelling of diffusional mass transfer in naturally fractured reservoirs

Cited by 25 publications

References 3 publications

Estimation of concentration‐dependent diffusion coefficients of gases in heavy oils/bitumen using experimental pressure‐decay data

Estimation of concentration‐dependent diffusion coefficients of gases in heavy oils/bitumen using experimental pressure‐decay data

Solubility Of CO₂ and C₂H₆ in heavy Oil and its Sara fractions

Numerical modeling of molecular diffusion and convection effects during gas injection into naturally fractured oil reservoirs

Contact Info

Product

Resources

About

Modelling of diffusional mass transfer in naturally fractured reservoirs

Cited by 25 publications

References 3 publications

Estimation of concentration‐dependent diffusion coefficients of gases in heavy oils/bitumen using experimental pressure‐decay data

Estimation of concentration‐dependent diffusion coefficients of gases in heavy oils/bitumen using experimental pressure‐decay data

Solubility Of CO2 and C2H6 in heavy Oil and its Sara fractions

Numerical modeling of molecular diffusion and convection effects during gas injection into naturally fractured oil reservoirs

Contact Info

Product

Resources

About

Solubility Of CO₂ and C₂H₆ in heavy Oil and its Sara fractions