Relative permeability estimates for Wolfcamp and Eagle Ford shale samples from oil, gas and condensate windows using adsorption-desorption measurements

Ojha, Shiv Prakash; Misra, Siddharth; Tinni, Ali; Sondergeld, Carl H.; Rai, Chandra

doi:10.1016/j.fuel.2017.07.003

Cited by 65 publications

(12 citation statements)

References 31 publications

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“…Because the affinity of the oil to different minerals is different, gas storage behavior in these different shales is different. In general, organic matter and clay minerals are oil-wet, quartz and feldspar are water-wet, and carbonate minerals are neutral-wet or preferentially oil-wet. , Note that the shale formations for oil development and the beds of interest for drilling and hydraulic fracturing in the U.S.A. are the interbedded carbonate and sandstone layers, then the mixed layers, and the shales. − In China, the targets for the shale oil development are mainly the continental shales, and the target layers are the interbedded tight sandstone and carbonate in the shale strata or laminated and pure shales …”

Section: Shale Mineralogy Pore Structure and Fluid Propertiesmentioning

confidence: 99%

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Pan

Liu

et al. 2021

Energy Fuels

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Shale oil has become an important oil resource over the past decade. The oil storage behavior, including the adsorbed oil and free oil, is one of the most important controlling factors for shale oil production. Because the shale oil storage behavior is largely determined by the fluid and solid interactions, this review first evaluates the shale mineralogy, pore structure, and oil properties. Then, the experimental methods to characterize the free oil and adsorbed oil are reviewed. The relationship between the oil storage behavior and shale and oil properties are then discussed. It is concluded from the literature work that the organic matter has the highest adsorption capacity for oil, followed by clay minerals, quartz, and calcite. While it is well-known that heavier oil components are adsorbed more than the lighter components, a relationship between the ratio of pore size to oil molecular size and the ratio of free oil to adsorbed oil is suggested and plotted. Finally, it is found from the literature that accurate experimental methods and theoretical models on free oil and adsorbed oil characterization are still missing; therefore, these topics require attention in future researches on shale oil.

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Section: Shale Mineralogy Pore Structure and Fluid Propertiesmentioning

confidence: 99%

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Pan

Liu

et al. 2021

Energy Fuels

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“…It is assumed that porous media consist of tortuous capillaries with variable lengths and diameters. According to fractal theory, the number of cumulative capillaries has been proven to obey the fractal scaling law [43]:…”

Section: Fractal Characteristics Of Porous Mediamentioning

confidence: 99%

The Percolation Properties of Electrical Conductivity and Permeability for Fractal Porous Media

et al. 2019

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Many cases have indicated that the conductivity and permeability of porous media may decrease to zero at a nonzero percolation porosity instead of zero porosity. However, there is still a lack of a theoretical basis for the percolation mechanisms of the conductivity and permeability. In this paper, the analytical percolation expressions of both conductivity and permeability are derived based on fractal theory by introducing the critical porosity. The percolation models of the conductivity and permeability were found to be closely related to the critical porosity and microstructural parameters. The simulation results demonstrated that the existence of the critical could lead to the non-Archie phenomenon. Meanwhile, the increasing critical porosity could significantly decrease the permeability and the conductivity at low porosity. Besides, the complex microstructure could result in more stagnant pores and a higher critical porosity. This study proves the importance of the critical porosity in accurately evaluating the conductivity and permeability, and reveals the percolation mechanisms of the conductivity and permeability in complex reservoirs. By comparing the predicted conductivity and permeability with the available experimental data, the validity of the proposed percolation models is verified.

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“…For instance, if organic matter forms continuous sublayers, it may cause fairly high oil and gas relative permeabilities, even at low hydrocarbon saturations, because it can decrease the flow tortuosity via nanometer‐sized oil‐wet flow paths. Here, we adjust two independent tortuosity parameters for the wetting and non‐wetting phases by fitting the Luckner's model to the shale relative permeability data points acquired via adsorption‐desorption experiments and analytically predicted by Daigle et al According to the best‐fitted models, solid lines in Figure , the tortuosity parameter is achieved very close to 2 and 0.5 for the wetting and nonwetting phases, respectively. Notably, the first tuned exponent is consistent with Burdine's equation and the latter is identical to an assumption made by Parker et al Applying the presented semi‐analytical approach and using the obtained saturation functions, the cumulative imbibed water and the size of the invaded zone are predicted for each case study.…”

Section: Workflow Of Semi‐analytical Modellingmentioning

confidence: 99%

Modelling shale spontaneous water intake using semi‐analytical and numerical approaches

Mohammadmoradi

Kantzas

2018

Can J Chem Eng

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Shale matrix water intake during hydraulic fracturing is considered undesirable due to the high volume of unrestrained water loss; however, it is also rewarding because it can reduce the possibility of groundwater contamination. The water intake also plays a dual role in changing the shale production performance; water imbibition into matrix pores can dramatically reduce the effective permeability and, at the same time, might enhance hydrocarbon production by creating adsorption-induced micro-fractures. Quantifying the formation intake capacity and its breadth is the key to optimizing fracturing operation, flowback, and production strategy. This work entails complementary semi-analytical and numerical analyses and investigates the effects of basic rock and fluid properties, wettability heterogeneity, and pore space connectivity on the shale imbibition characteristics. We consider a semi-analytical formulation of the spontaneous water imbibition, together with model results and validations, and try to provide a framework to link the capillary imbibition capacity/rate to lab-scale observations. The core-scale measurements provide input for a sensitivity study on the matrix imbibition capacity in six shale plays in North America. The results suggest that rock permeability, hydraulic tortuosity, and initial and residual hydrocarbon saturations are among the most influential factors on the spontaneous water intake during shut-in periods. Direct quasi-static simulations are then conducted through a submicron tomography image of the Eagle Ford shale, and two-phase pore-level fluid occupancies are reconstructed during spontaneous and forced imbibition processes. According to the numerical results, the presence of continuous organic matter laminae can lower the destructive effects of water imbibition on the hydrocarbon permeability.

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Relative permeability estimates for Wolfcamp and Eagle Ford shale samples from oil, gas and condensate windows using adsorption-desorption measurements

Cited by 65 publications

References 31 publications

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

The Percolation Properties of Electrical Conductivity and Permeability for Fractal Porous Media

Modelling shale spontaneous water intake using semi‐analytical and numerical approaches

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