An Experimental Phase Diagram of a Gas Condensate Reservoir

Kamari, Ehsan; Shadizadeh, Seyed Reza

doi:10.1080/10916466.2011.553652

Cited by 5 publications

(4 citation statements)

References 10 publications

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“…Importantly, the liquid volume small compared to the gas volume with a maximum fraction of no more than 3% and this is in good accordance with should be expected from the fluid composition chosen as well as known gas condensates of this type. 17 The retrograde effect is easily visualized from MD trajectories, snapshots of which are shown in Figure 2b: upon compression, liquid volume increases on the low pressure end of the isotherm, but at higher pressures, the liquid droplets are interrupted by the high energy gas phase and the liquid-vapor phase boundary becomes less distinct. Because the liquid and vapor regions become increasingly less distinct in the retrograde region, liquid volumes are difficult to measure; however simple visualization indicates that the liquid fraction is maximized at approximately 70 bar.…”

Section: Examples and Preliminary Resultsmentioning

confidence: 99%

Molecular Dynamics Simulations of Retrograde Condensation in Nanoporous Shale

Welch¹,

Piri²

2015

Unconventional Resources Technology Conference

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Molecular Dynamics (MD) simulations are employed to illuminate phase behavior of a complex petroleum fluid with a focus on retrograde phase behavior under nano-confinement typical of tight shale. First, a fluid composed of hydrocarbons ranging from methane to eicosanes is modeled in the united atom, Transferrable Potentials for Phase Equilibrium (TraPPE) force field, and a retrograde isotherm for the bulk fluid is demonstrated. This fluid is then isothermally compressed and decompressed inside solid organic pores. Pressure is modulated by pistons on opposite ends of the fluid volume allowing for simulation of pressure gradients across the system. In the present work, condensation in cylindrical pores 20 nm long is examined for cross sectional pore diameters of 3 and 4 nm. Preliminary results indicate that for this fluid, sealing due to capillary condensation is significant for the system having a cross sectional diameter of 3 nm, while the fluid is less dense in the wider, 4nm pore in which little accumulation of large molecules is observed in the center of the pore. For the narrower channel, sealing and flow inhibition persists under pressure gradients as high 350 bar.

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Section: Examples and Preliminary Resultsmentioning

confidence: 99%

Molecular Dynamics Simulations of Retrograde Condensation in Nanoporous Shale

Welch¹,

Piri²

2015

Unconventional Resources Technology Conference

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“…These hydrocarbon samples include two gas condensate samples and one oil sample. Two condensate fluid samples will be denoted by E and F, which are gathered from studies of Gharesheikhloo and Moayyedi, and Kamari and Shadizadeh, respectively. Furthermore, the oil sample G is selected from the Mohebbinia et al study .…”

Section: Resultsmentioning

confidence: 99%

Optimal distribution function determination for plus fraction splitting

2019

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Reservoir fluid modelling is one of the most important steps in reservoir simulation and modelling of flow lines as well as surface facilities. One of the most uncertain parameters of the reservoir fluids is the plus fraction. An accurate and consistent splitting scheme can reduce this uncertainty and as a result, enhance the modelling of reservoir fluids. The existing schemes for splitting plus fractions are all based on assuming a specific mole fraction-molecular weight distribution with predefined constant values that may yield inaccurate and inconsistent results. In this study, an optimization-based algorithm was developed to determine the aforementioned controlling parameters of the plus fraction distribution function, enforcing the relationship between specific gravity and molecular weight of the single carbon numbers (SCNs). The introduced optimizationbased splitting technique was applied to different samples, covering a wide range of reservoir fluids, including gas condensates, volatile oils, black oils, and heavy oils. The results showed that the proposed technique yielded a more consistent molecular weight-mole fraction distribution concerning the experimental extended analysis of plus fractions, yielding an average relative error of 25.8 % compared to 76, 33.6, and 45.9 % for the Katz, Ahmed, and Whitson methods, respectively. It was also shown that the proposed method results in more accurate and more consistent phase behaviour predictions than the existing methods concerning the experimental data. Furthermore, the results showed that the introduced optimization-based method yields monotonic split samples regarding specific gravity and molecular weight, while the conventional techniques do not guarantee to preserve the monotonicity.

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“…The retrograde phenomenon is common in the development of condensate gas reservoirs due to their special fluid properties, which results in the precipitation of condensate oil near wells and leads to a reduction in gas well production [4][5][6][7]. To study the retrograde phenomenon and assess its impact on the yield during the development of condensate gas reservoirs, substantial research has been conducted on condensate gas phase characteristics, the evaluation of retrograde pollution, and the impact of retrograde pollution on production, which has mainly been carried out through physical experiments and numerical simulation methods [8][9][10][11]. In relation to the phase characteristics of condensate gas reservoirs, Onoabhagbe et al [12] propose a novel approach for tracking the phase change based on simulating the formation of condensate blockage in tight as well as low-and high-permeability reservoirs; Wang et al [13] improve the Peng-Robinson model to simulate the phase change of condensate gas and calculate the Processes 2024, 12, 522 2 of 14 volume of condensate oil considering the effect of capillary forces; and Abbasov et al [14] analyze the influence of gas components on the retrograde condensation of condensate gas based on the results of retrograde condensation simulation experiments.…”

Section: Introductionmentioning

confidence: 99%

A Novel Method for the Quantitative Evaluation of Retrograde Condensate Pollution in Condensate Gas Reservoirs

Zhao,

Zhang,

Gao

et al. 2024

Processes

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During the development of condensate gas reservoirs, the phenomenon of retrograde condensation seriously affects the production of gas wells. The skin factor caused by retrograde condensation pollution is the key to measuring the consequent decrease in production. In this study, a multiphase flow model and a calculation model of retrograde condensate damage are first constructed through a dynamic simulation of the phase behavior characteristics in condensate gas reservoirs using the skin coefficient, and these models are then creatively coupled to quantitatively evaluate retrograde condensation pollution. The coupled model is solved using a numerical method, which is followed by an analysis of the effects of the selected formation and engineering parameters on the condensate saturation distribution and pollution skin coefficient. The model is verified using actual test data. The results of the curves show that gas–liquid two-phase permeability has an obvious effect on well production. When the phase permeability curve changes from the first to the third type, the skin coefficient increases from 3.36 to 26.6, and the condensate precipitation range also increases significantly. The distribution of the pollution skin coefficient also changes significantly as a result of variations in the formation and dew point pressures, well production, and formation permeability. The average error between the calculated skin of the model and the actual test skin is 3.87%, which meets the requirements for engineering calculations. These results have certain significance for guiding well test designs and the evaluation of condensate gas well productivity.

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An Experimental Phase Diagram of a Gas Condensate Reservoir

Cited by 5 publications

References 10 publications

Molecular Dynamics Simulations of Retrograde Condensation in Nanoporous Shale

Molecular Dynamics Simulations of Retrograde Condensation in Nanoporous Shale

Optimal distribution function determination for plus fraction splitting

A Novel Method for the Quantitative Evaluation of Retrograde Condensate Pollution in Condensate Gas Reservoirs

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