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Journal of Petroleum Science & Engineering
Elsevier Science B.V.
Journal of Petroleum Science & Engineering

Elsevier Science B.V.

0920-4105

Journal of Petroleum Science & Engineering/Journal Journal of Petroleum Science & Engineering
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    Recent advances in oil/water separation using nanomaterial-based filtration methods for crude oil processing-a review

    Sonia MirAbbas NaderifarAli morad Rahidi
    17页
    查看更多>>摘要：The separation of water is essential in crude oil processing. The presence of water-in-crude oil emulsions increases the cost of production and transportation of petroleum oil and causes pump failure, pipeline corrosion and other problems such as catalysts poisoning in downstream. The present essay aims to provide an overview of the state-of-the-art methods of water and oil separation, particularly practical applications in industry. Salt content causes problems such as corrosion, fouling, or catalyst degradation in the refinery. Water and salt content should be less than 0.1 wt% of the crude oil to control the mentioned problems. For oil and water separation, industrial separation systems such as centrifuges are used but this separation is not complete and the water or oil content is not within the permissible limit. So it is necessary to use a complementary system. Demulsifiers and desalters, which have played a major role in the industry, have problems due to their high dependence on viscosity, high cost, environmental impact, formation of fine secondary droplets, energy consumption, etc. Nanomaterials, especially nanostructures of silicone and carbon, with a better performance have been investigated as a subsequent recommendation rather than demulsifiers in some studies. Presenting environmental stimuli for switch wettability that possess easy applying for industrial operation as well as find a smart material with a similar efficiency to demulsifiers will definitely be able to compete with demulsifiers and other conventional methods and replace with them. Changing surface properties by functionalization of the surface or surface charging followed by hydrophilic-lipophilic balance (HLB) adjustment can enable the surface to do dewatering process or even act as a smart separator with switching from W/O separation to O/W or vice versa. Therefore, this article reviews nanomaterial-based filtration methods as an efficient method for separating water and oil, and studies the advances that researchers have made so far.
      原文链接:
    • NSTL

    Lithology Prediction of One-dimensional Residual Network Based on Regularization Constraints

    Jiajia ZhangYonggen LiZhuofan Liu
    12页
    查看更多>>摘要：Lithology prediction is an important work in seismic reservoir prediction. Deep learning can explore the nonlinear mapping relationship between lithology and seismic properties, and achieve efficient and accurate lithology prediction. On the one hand, when the depth of the network increases, the problem of model degradation is prone to occur. On the other hand, due to the small sample size of logging data, overfitting is common when deep learning methods are used for lithology prediction. We apply a one-dimensional residual network to lithology prediction with regularization constraints on the overfitting phenomenon of the model. According to the change of loss function under different regularization constraint methods, the influence of regularization constraints on model overfitting is analyzed. Compared with the initial model, the prediction accuracy of the model with regularization constraints in the validation set is improved from 48.81% to 59.87%. When considering adjacent Uthology, the validation set accuracy improves from 89.37% to 91.54%. The proposed model achieves 92.65% accuracy on the test set. Applying a regularized residual network model to seismic data pre diction can effectively indicate the distribution of subsurface lithology.
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    • NSTL

    Enhanced pyrolysis of Huadian oil shale at high temperature in the presence of water and air atmosphere

    Wei GuoXu ZhangSunhua Deng
    11页
    查看更多>>摘要：The liquid water injected at a high temperature combined with oxygen pyrolysis of oil shale is firstly studied. The pyrolysis was conducted at different temperatures and water to oil shale mass ratios (W/OS) in a self-reformed Fischer Assay retort under an air atmosphere to identify the effect of water on the distribution and characteristics of the oil shale products. The shale oil yield at a W/OS ratio of 0.5:10 was higher than that of the no water case under an air atmosphere and the highest yield was approximately 450 °C. With the same shale oil yield as that obtained from the Fischer Assay, the pyrolysis temperature decreased by approximately 78 °C with a W/OS of 0.5:10 under an air atmosphere. Pyrolysis of oil shale with different W/OS ratios significantly increased the shale oil yield from 17.03% to 20.00% and decreased the semicoke yield from 68.42% to 68.20% with an increasing W/OS from 0:10 to 1.5:10 under an air atmosphere at 450 °C. As the W/OS increased to 0.75:10, the alkane and alkene contents increased, while the aromatic hydrocarbon content decreased. Water increased the content of the heavy fractions in the shale oil by weakening the adsorption of macromolecular compounds on the minerals and prompting oil migration. The presence of water slightly increased the H/C and S contents in the shale oil but reduced the content of N. The effect of water on the distribution and characteristics of the products was caused by multiple control mechanisms in the pyrolysis process, including chemical, migration, the interaction with oxygen effect.
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    • NSTL

    Flow capacity characterization of unconventional natural gas bearing rocks using digital rock physics: A comparison between advection and diffusion

    Rui Xu
    8页
    查看更多>>摘要：Experimental flow capacity characterization of unconventional rocks is a nontrivial task, and the relative contribution of advective vs. diffusive flow mechanisms remains illusive. Herein we apply a digital rock physics workflow to systematically compare the advection and diffusion behavior of supercritical methane in two 3D reconstructed unconventional shale and coal core samples. Nitrogen sorption experiments and scanning electron microscope observations are combined to inform the construction of representative pore network models. For advection modeling, we consider the nanometer-scale confinement effect and pore shape effect, while for diffusion modeling the contributions of Fick diffusion, transitional diffusion, and Knudsen diffusion are considered separately based on the Knudsen number. The effect of pore size, shape, pressure, and temperature on methane flow capacity in a single nanopore is first studied. Then the apparent permeability and effective diffusivity of the two reconstructed nanoporous media are calculated and compared. We demonstrate that at reservoir pressure and temperature conditions, diffusion contributes to mass flux (above 10%) only in micropores and small mesopores (< 10 nm). For most realistic unconventional rocks, the contribution of bulk diffusion can be neglected when estimating the flow capacity.
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    • NSTL

    Application of a novel amphiphilic polymer for enhanced offshore heavy oil recovery: Mechanistic study and core displacement test

    Xiao WangWanfa LiuLeiting Shi
    13页
    查看更多>>摘要：A molecular modified polyacrylamide with Gemini surfactant monomers, named as HA1, was evaluated in this paper as an alternative to enhance the offshore heavy oil recovery. The physical properties of HA1 solution including apparent viscosity, Theological properties, static adsorption, interfacial activities (IFT, interfacial visco-elasticity and contact angle), emulsification ability, as well as oil recovery capacity were comprehensively investigated. Our results indicate that due to the hydrophobic and Gemini surfactant monomers on the acryl-amide backbone, this novel amphiphilic polymer possesses more advanced functions than conventional polymers. HA1 demonstrates pronounced aqueous-phase viscosifying ability by forming 3D network in solution when the concentration is above CAC. In addition, the IFT, interfacial visco-elasticity and contact angle response illustrate that HA1 interacts strongly with the oil-phase which gives rise to its significant interfacial activity. Thereby, HA1 is able to reduce the heavy oil viscosity by emulsifying oil into water phase even at relatively low water content (20%) and also avoids dehydration difficulty by reducing the oil-brine interfacial rigidity, Furthermore, the asphaltene morphology change due to HA1 observed by SEM and AFM proves that HA1 can disperse the asphaltene aggregates in the crude oil, leading to a direct reduction of the heavy oil viscosity. At last, the coreflooding in an artificially synthesized triple-layered porous media shows that HA1 gives rise to an additional oil recovery of 27.04%, at the optimum concentration of 1600 ppm, by improving sweep efficiency, microscopic efficiency and dispersion of the asphaltene aggregates. Therefore, the potential of HA1 to enhance heavy oil recovery is comparable to traditional multi-component polymer-surfactant flooding. Since HA1 is single-component, it can also mitigate incompatibility issues like chromatography separation and surfactant-polymer interactions. Overall, this new self-assembly system shows potential for applications in heavy oil recovery.
      原文链接:
    • NSTL

    New insights into the interaction between asphaltene and hydrolyzed polyacrylamide at the oil-water interface based on emulsion stability

    Wei LiuHongrui FuXiaojun Sun
    11页
    查看更多>>摘要：Asphaltene and hydrolyzed polyacrylamide (HPAM) are important components for stabilizing polymer-containing oil water/sludge in oilfield. In this study, the effects of asphaltenes concentration, HPAM concentration, pH, oil/water ratio and salinity on the storage stability and shear rheology of the emulsions were investigated. The results showed that the addition of HPAM could change the emulsion type from W/O to O/W, and the shear modulus of the emulsions stabilized by HPAM and asphaltenes were 10 times lower than that of asphaltenes emulsions. As the pH increased from 4 to 11, the emulsion type changed from W/O to O/W and the shear modulus of the emulsion decreased by 2 orders of magnitude. The addition of inorganic salts destroyed the asphaltene interfacial film and reduced the stability of the emulsion. The interaction of amide and carboxylic acid groups in HPAM molecules with asphaltenes was investigated through interfacial properties. The carboxylic groups and amide groups of HPAM molecules could interact with the interfacial active components of asphaltenes and formed a carboxyl-asphaltene-amide complex unit, which made the asphaltene molecules 'anchorage' on the HPAM molecular chain. This study is intended to provide a theoretical basis for the efficient and environmentally friendly treatment of polymer-containing oil water/sludge in oilfield.
      原文链接:
    • NSTL

    Using high-intensity water flooding relative permeability curve for edicting mature oilfield performance after long-term water flooding in order to realize sustainable development

    Renyi CaoZhihao JiaLinsong Cheng
    13页
    查看更多>>摘要：Most of the mature oilfields are on the verge of being abandoned. Drilling infill wells or chemical displacement is a standard method to improve mature oilfield performance. But these methods are not economical. For the sustainable and economic development of mature oilfields, large displacement natural water flooding was applied for improving mature oilfield performance. After high-intensity water flooding, most of the mature oilfields are in high water-cut and high recovery stages, and it is difficult for performance prediction. Relative permeability is an important characteristic of multiphase flow in porous media and also an important parameter for dynamic prediction of high water cut stage. In this study, the ratio of the flow-through water flow to the pore area of the displaced cross-section, i.e., the displacement flux (P.A.), was applied to characterize the scouring intensity. Two types of relative permeability curves were obtained through high-intensity water flooding (HIWF) experiments, including one type of continuous relative permeability curve of different displacement fluxes (Type I HIWF relative permeability curve) and the second type of multiple relative permeability curves of different displacement fluxes under re-saturated conditions (Type II HIWF relative permeability curve). In addition, a two-dimensional five-point pattern model was established to compare the calculation results of one conventional type of relative permeability curve and two types of HIWF relative permeability curve. Finally, a numerical model of a real reservoir in a mature oilfield was generated to test the method. The results demonstrate that using Type I HIWF relative permeability curve is fast and accurate to characterize the performance of the ultra-high water cut stag, which guides the application of high-intensity long-term water flooding in order to improving the ultimate oil recovery (IOR). So as to help the mature oilfields achieve economic and sustainable development.
      原文链接:
    • NSTL

    Sand-rich gas hydrate and shallow gas systems in the Qiongdongnan Basin, northern South China Sea

    Jinfeng RenCong ChengPengfei Xiong
    15页
    查看更多>>摘要：In 2019, the sand-rich gas hydrate and shallow gas (GHSG) reservoirs have been drilled in the Qiongdongnan Basin, northern South China Sea. As a conventional energy resource, shallow gas can provide a continuous source of gas for gas hydrate accumulation, which is also the focus of future research on gas hydrates. Using core-log-seismic data, the distributions and sedimentary environments of the sand-rich GHSG reservoirs were identified and characterized. Then, the sand-rich GHSG systems were illustrated, and the interactions of gas hydrate with shallow gas were analyzed in details in the Qiongdongnan Basin. At last, an accumulation model for the GHSG systems was proposed. This model shows that natural gas in the deep parts of the hydrocarbon-rich sag migrated laterally to the study area to form deep natural gas reservoirs, and then is transported vertically through gas chimneys to form GHSG system. The system mainly includes gas sources, gas migration pathways, reservoirs, and seals, of which gas migration pathways are key influencing factors. Moreover, the whole system is a dynamically balanced system in which shallow gas reservoirs can provide adequate gas for gas hydrate formation; meanwhile, gas hydrates can be seals to prevent the leakage of free gas and facilitate a larger-scale shallow gas reservoir formed, so these two items are complementary and indispensable in the system.
      原文链接:
    • NSTL

    Storage space development and hydrocarbon occurrence model controlled by lithofacies in the Eocene Jiyang Sub-basin, East China: Significance for shale oil reservoir formation

    Chao LiangJing WuYingchang Cao
    19页
    查看更多>>摘要：Complex mineral composition, multiple depositional processes, and strong reservoir heterogeneity cause the complexity and uniqueness of a lacustrine shale oil reservoir. Understanding the storage space development and hydrocarbon occurrence model should facilitate the analysis of the shale oil reservoir and hydrocarbon accumulation in lacustrine shales. In this study, the storage space development model for different lithofacies and the modes of hydrocarbon occurrence in different storage space were analyzed in the Es4s-Es3x shale in the Jiyang Sub-basin, East China, based on thin-section and field emission scanning electron microscopy (FE-SEM) observations, X-ray diffraction (XRD) analysis, physical property testing, and geochemical analysis. Inorganic pores, particularly recrystallization intercrystalline pores in calcite, are the key matrix pores for lacustrine shale oil. However, the types and abundance of storage space are noticeably different in various lithofacies. The hydrocarbon occurrence is mainly manifested in three states: (A) free state in interlaminar fractures, structural fractures, and abnormal pressure fractures; (B) adsorbed state in organic pores, intercrystalline pores in pyrite, and floccule pores; and (C) free state in large pore spaces, including dissolution pores and recrystallization intercrystalline pores, which can form a continuous hydrocarbon accumulation. The hydrocarbon generation potential and thermal maturity are closely associated with the lithofacies and mineral composition. The matching mechanisms of pore formation as well as hydrocarbon generation, migration, and accumulation are favorable. Among the various lithofacies, the organic-rich calcareous shale has abundant storage space, high porosity, total organic carbon content, and hydrocarbon potential, making it a 'sweet spot' for shale oil exploration.
      原文链接:
    • NSTL

    Effective treatment of geometric constraints in derivative-free well placement optimization

    Amy ZouTianrui YeOleg Volkov
    25页
    查看更多>>摘要：A robust workflow for optimizing the placement of multiple deviated wells subject to challenging geometric constraints is presented and applied. The workflow entails the use of population-based global stochastic search algorithms in conjunction with a solution-repair method. The repair procedure, which involves a gradient-based optimization prior to flow simulation, reduces constraint violations via projection of the infeasible solutions onto (or toward) feasible space while minimizing the deviation between the repaired and original solutions. The constraints considered include well length, interwell distance, well-to-boundary distance, and the requirement that wells not cross faults. The repair procedure is implemented with three different core optimization algorithms - particle swarm optimization, iterative Latin hypercube sampling, and differential evolution. Through extensive numerical tests involving the placement of multiple deviated wells, we demonstrate that it is necessary to tune the hyperparameters associated with the core optimizers when these optimizers are used with the repair procedure. In the first example (Egg model), for instance, with differential evolution as the core optimizer, we show that the best-case hyperparameters provide feasible solutions and a 30% improvement in objective function value relative to base-case hyperparameters. The best-case hyperparameters from this example are then used directly in the second example, which involves the placement of seven deviated wells in the Brugge model. For this example, with no additional tuning, we achieve feasibility and a 42% improvement in objective function value relative to base-case hyperparameters, suggesting that the tuned hyperparameters are to some extent transferable between problems.
      原文链接:
    • NSTL