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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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    Preferential flow control in heterogeneous porous media by concentration-manipulated rheology of microgel particle suspension

    Lei, WenhaiLi, QiangqiangYang, Hai-EnWu, Tian-Jiang...
    12页
    查看更多>>摘要：Preferential flow is commonly encountered but decreases the efficiency of multiphase displacement in most industrial processes. Microgel particle suspensions with polymer/colloid duality are a potential candidate to overcome such nonuniform flow. In this study, a novel mechanism of preferential flow control in heterogeneous porous media by concentration-manipulated rheology of microgel particle suspension was proposed, which is strongly supported by microfluidic experiments and pore-scale simulations. By varying the injection concentration, displacement processes were identified to three transport modes: the channeling mode at a low injection concentration, the synchronous mode at an intermediate injection concentration, and the fluctuation mode at a high injection concentration. Concentration-manipulated rheology and nonuniform particle concentration distribution in different layers make it possible to realize uniform flow in heterogeneous porous media. It was demonstrated that the multiphase processes at low/intermediate injection concentrations are dominated by twophase flow with particle advection-diffusion in the invading phase but that at high injection concentrations disobeys this model due to local particle rapid enrichment by particles lagging behind the displacing fluid. During the displacement process, an intermediate injection concentration always exhibits the optimal synchronous displacement by self-adaptive concentration manipulation in different layers. However, concentration manipulation at low injection concentrations was too weak to suppress preferential flow, and a high injection concentration was sensitive enough to alternate preferential flow pathways frequently, which will lead to oleic ganglia being trapped. These findings deepen the understanding of microgel particle suspension dynamics in heterogeneous porous media and shed unique insights for their applications, such as enhanced oil recovery and CO2 sequestration.
      原文链接:
    • NSTL
    • Elsevier

    Fast evaluation of pressure and saturation predictions with a deep learning surrogate flow model

    Maldonado-Cruz, EduardoPyrcz, Michael J.
    14页
    查看更多>>摘要：Numerical models for flow through porous media are essential for forecasting subsurface fluid flow response to support optimal decision-making to develop subsurface resources such as groundwater, geothermal, and oil and gas. For reservoir engineering, numerical flow simulation modeling is applied to support and maximize well ultimate recovery and recoverable reserves to maximize project economics and safety while minimizing environmental impacts. Subsurface models explore subsurface uncertainty based on integrating geological, geophysical, petrophysical, and reservoir engineering data and expert interpretations. To evaluate uncertainty, we rely on multiple geostatistical subsurface heterogeneity realizations paired with flow simulation forecasts to test the sensitivity of various reservoir development parameters and build an uncertainty model of reservoir performance. However, with large reservoir models, numerical flow simulation time increases, leading to a significant amount of professional time and computational effort that increases project costs, and increases cycle times resulting in delay or diminished decision quality. This issue motivates the utilization of surrogate, computationally efficient approximative flow models. Current methods focus on prediction accuracy and minimizing prediction error. When uncertainty is significant, prediction accuracy is insufficient, and we must consider the entire uncertainty distribution. We propose a new and general workflow to generate accurate and precise machine learning-based surrogate flow models to predict the relationship between the reservoir rock and fluids, development parameters, and the reservoir flow simulation responses. We train a deep convolutional neural network using the results from a threedimensional two-phase flow simulator. Next, we use the trained model to generate ensemble predictions from the flow surrogate to evaluate the uncertainty based on the development parameters and geological information. The machine learning-based surrogate model uses exhaustive subsurface predictor features, porosity, permeability, well position, and an engineered feature representing non-dimensional time as input to predict exhaustive subsurface response features, pressure, and saturation distribution over discrete time steps as the output. The proposed workflow integrates the spatiotemporal aspect of subsurface flow modeling. It allows the practitioner engineer to explore subsurface uncertainty without the entire computational cost of numerical flow simulation to support optimum, timely development decision-making.
      原文链接:
    • NSTL
    • Elsevier

    Integrated optimization of fracture parameters for subdivision cutting fractured horizontal wells in shale oil reservoirs

    Deng, HaiyangSheng, GuanglongZhao, HuiMeng, Fankun...
    11页
    查看更多>>摘要：Horizontal well with subdivision cutting fracturing technology is a new technical way to improve the efficient development of shale reservoirs. Subdivision cutting fracturing has the characteristics of stronger inter-fracture interference, more variable parameters and constraints. This fracturing technology has no efficient method to optimize the discrete and continuous fracture parameters integrally. A new automatic integrated optimization algorithm is proposed. The algorithm adopts the SPSA nested binary search algorithm to optimize the discrete and continuous fracture parameters. Considering the flow mechanism of multi-scale media in shale reservoirs, a numerical flow simulation model of subdivision cutting fractured horizontal wells is established. Then, taking the NPV as the objective function, a multi-parameter integrated optimization model is established. Make the method apply to a typical test shale reservoir. The optimization results show that the NPV of the optimum fracture parameter combination is 37.69%-57.36% higher than that of the uniform fracture distribution combination. And the optimum fracture combination presents a spindle-like distribution. This method is applied to an actual shale reservoir in Xinjiang to verify the broad application. The fracture parameter combination of two parallel horizontal wells in the reservoir is optimized. The optimization results show that the NPV has been dramatically improved, with an increasing range of 37.94%-96.84%. And the fractures of two adjacent horizontal wells present zipper staggered distribution. The integrated optimization method of fracture parameters can provide theoretical guidance for hydraulic fracturing design.
      原文链接:
    • NSTL
    • Elsevier

    Comprehensive evaluation of self-healing polyampholyte gel particles for the severe leakoff control of drilling fluids

    Yang, LiliXie, ChunlinAo, TianCui, Kaixiao...
    11页
    查看更多>>摘要：Lost circulation has been a serious problem to be solved in many drilling practices during oil, gas and geothermal well drillings. Many materials have been developed and evaluated for the purpose. However, their performance to plug severe leakoff is very limited. Herein, an injectable self-healing hydrogel based on polyampholyte with sulfonated and quaternary ammonium functionalities (P(MPTC-co-NaSS)) was developed and comprehensively evaluated to prevent the severe loss of fluids to formation. By incorporating cation-7t (7t is for aromatic residues) interaction, the hydrogel shown self-healing property and robustness in severe environment (temperature, salt) by comparison with other hydrogels merely consisting of cation-anion and H-bonding interactions. Aromatic residues enhanced thermal stability above 310 degrees C. The plugging measurement shown that an addition of 2 wt% dried gel particles can plug high-permeability formation and endure a high pressure of 6 MPa, produce much lower circulation loss and result in a dramatically increased loss volume reduction rate (63.5%) compared with a commercial polymer gel product and an inert material (9.4%) after a self-healing process. Markedly, P(MPTC-co- NaSS) can be used in a wide range of formation temperature (as high as 150 degrees C) and salt concentrations (NaCl, CaCl2, as high as 15 wt %). In addition to suitable particle size and mechanically robustness, it was also attributed to the soft, swelling, deformable, toughness and self-healable features of P(MPTC-co-NaSS) gel par-ticles as well as the strong adhesion to negatively charged formations in water, even under high thermal and saline condition. These characteristics also contributed to a long-term plugging performance, beneficial to avoid repeated lost circulation in drilling operation. Besides, this self-healing polyampholyte gel particles dispersed well in saline fluid and maintained stable rheological properties after hot rolling, which was favorable to drilling fluid circulation. This study shown the application potential of self-healing materials as plugging material candidate in petroleum drilling industry.
      原文链接:
    • NSTL
    • Elsevier

    Lithofacies, mineralogy, and pore types in Paleozoic gas shales from Western Peninsular Malaysia

    Ibad, Syed MuhammadPadmanabhan, E.
    17页
    查看更多>>摘要：An experimental study including Fourier Transform Infrared (FTIR), thin section petrography, scanning electron microscope (SEM) imaging, and low-pressure nitrogen adsorption analysis has been conducted to assess the mineralogy, lithofacies, pore types, and pore properties of the potential Paleozoic gas shales from Western Peninsula (WP) Malaysia. In WP Malaysia, shale samples from seven Paleozoic Formations were investigated and classified into four age categories. FTIR analysis documented the presence of aromatic out of plane and in plane bending, aliphatic CH bending, OH functional group, and presence of quartz, carbonates, kaolinite, and illite minerals. Four lithofacies identified from the petrographic analysis of the Paleozoic shale include silica-rich argillaceous mudstone (SAM), clay-rich siliceous mudstone (CSM), silica dominated lithofacies mudstone (SD), and mixed carbonate mudstone (MCM). In comparison, the mineral content and lithofacies found in Paleozoic shales are close to the Niutitang, Longmaxi, Marcellus, and Eagle Ford shales. Furthermore, with high organic matter content, laminated fabric, and with more brittle mineralogy, SD lithofacies would be a highly promising type of lithofacies in WP Malaysia. FESEM studies show that organic matter pores, interparticle pores, and intraparticle pores are the main pore types. Pore sizes analyze through N-2 adsorption reveal radii of lesser than 25 nm contribute mainly to porosity and total pore volume. Micropore volume of the WP Malaysia shale was found to be greatly similar to hot shales from USA and China, while surface area values of only older Paleozoic shales, i.e., S-D and Devonian, are close to USA shales.
      原文链接:
    • NSTL
    • Elsevier

    Maturity and depositional controls on compound-specific sulfur isotope values of saline lacustrine source rocks in the north Dongpu Depression, Bohai Bay Basin

    Ke, ChangweiLi, SumeiGreenwood, PaulHe, Nannan...
    16页
    查看更多>>摘要：Source rocks and oil sands from the northern Dongpu Depression have been analyzed by gas chromatography multicollector inductively coupled plasma mass spectrometry (GC-MC-ICP MS) to investigate the compound-specific sulfur isotope (delta S-34) values of saline lacustrine source rocks. The samples were also subject to more traditional organic geochemical analyses including hydrocarbon biomarker detection by gas chromatography/mass spectrometry (GC/MS), carbon and oxygen isotopic analysis by isotope ratio mass spectrometer, and major and trace inorganic element analysis. delta S-34(OSCs) values measured for a limited number of organic sulfur compounds (OSCs) showed a quite large range (5.16 parts per thousand-44.73 parts per thousand). The source rocks and oil sands could be separated into two groups with delta S-34 values above or below 25.00 parts per thousand. The first group with delta S-34 25.00 parts per thousand, were primarily the Weicheng source rocks, which also typically showed an increase in delta S-34 values with increasing alkylation. The second group had delta S-34 < 25.00, the delta S-34 of dibenzothiophenes showed a positive correlation with the concentration of the saturated hydrocarbon fraction of rocks, and a negative correlation with the polar (resin + asphaltene) fraction. The delta S-34(OSCs) show obvious positive correlation with gammacerane/C-31 hopane and C-35/C-34 hopanes and excellent correlation with contents of minerals and ratios of trace elements, reflecting a S-34 enrichment in closed evaporative environment (conducive to the sulfurisation of organic matter) and relative S-34 depletion in terrestrial environments. These trends identify the depositional environment of the source rocks as one of controls on delta S-34(OSCs) values. Thermal maturity was also observed to influence delta S-34(OSCs) values, becoming heavier with increasing maturity. There was a good result of oil-source rock correlation by delta(SOSC)-S-34 in this study. This study demonstrates the contribution delta S-34(OSCs) data can make to oil-oil and oil-source rock correlations as well as providing further evidence of their sensitivity to depositional environments and thermal maturity.
      原文链接:
    • NSTL
    • Elsevier

    The effect of resins concentration and polarity on the viscosity and impedance of electrically-treated waxy oils

    Xie, YiweiLi, HongyingDing, YifeiZhang, Chaoyue...
    8页
    查看更多>>摘要：Applying an electric field to waxy oil may significantly improve its cold flowability. Our previous study has demonstrated that the accumulation of asphaltenes and resins on the surface of wax particles, i.e., interfacial polarization of wax particles, is the essential mechanism of this electrorheological phenomenon. The influence of asphaltenes concentration on the performance of the electrical treatment has been studied. In this paper, the influence of the concentration of resins, the most abundant non-hydrocarbon component in crude oil, on electrically-treated waxy oil's viscosity and impedance was investigated for the first time by using model oils containing resins in the concentration range of 0.05 wt% - 5.00 wt%. It is found that the effect of resins concentration on viscosity and impedance is not monotonous, with both the viscosity reduction and impedance increment induced by the electric field decreased first and then increased with increasing resins concentration at a given amount of precipitated wax. Increasing the polarity of resins would alleviate the viscosity reduction and impedance increment. This work further demonstrates that resins accumulation on the wax particles surface does occur.
      原文链接:
    • NSTL
    • Elsevier

    Modeling of viscosity of unstable crude oil-water mixture by characterization of energy consumption and crude oil physical properties

    Luo, HaijunWen, JiangboWang, ZhihuaLv, Chunlei...
    14页
    查看更多>>摘要：When oilfield development enters the middle and late stages, the crude oil-water mixture (COWM) produced from oil wells often has a high water cut and cannot form a stable emulsion. The traditional viscosity model of an emulsion is not suitable for this unstable mixture. Mastering the viscosity characteristics of the unstable crude oil-water mixture with high water cut (UCMH) for pipeline transportation of such mixtures is important. The apparent viscosities of UCMH (water cut of mixture ranging from 0.70 to 0.90) for 16 crude oils were determined via the stirring viscometric method. The results showed that the apparent viscosity of UCMH decreased with increasing shear rate, water cut of mixture, and temperature, demonstrating the property of shear thinning. The apparent viscosity of UCMH did not depend on the content of single surfactants such as resins, asphaltenes, waxes, and mechanical impurities but was closely related to the content of the above-mentioned combinatorial surfactants. The parameter exergy loss rate of shear that describes energy consumption was determined to characterize the external shear action on UCMH, which can fully reflect the essence of the mechanical energy consumption in the emulsifying process under different shearing conditions. A new viscosity model for UCMH was established by the quantitative characterization of the energy consumption and crude oil physical properties (i.e., saturate content, aromatic content, surfactant content, acid value, and crude oil viscosity). In light of the statistical results of 336 groups of validation experimental data from four crude oils, the average relative deviation between the apparent viscosity calculated by the new model and the measured apparent viscosity of UCMH was 5.3%, which is considerably better than the traditional emulsion viscosity models, that is, the Einstein, Vand, Taylor, and Richardson models.
      原文链接:
    • NSTL
    • Elsevier

    A qualitative-quantitative approach for studying the impact of facies and diagenesis control on the rudist biostrome of the Sarvak formation, Abadan plain, SW Iran

    Sabouhi, MostafaMoussavi-Harami, RezaKadkhodaie, AliRezaee, Payman...
    15页
    查看更多>>摘要：Carbonate reservoir properties and their heterogeneities are of the main issues in reservoir qualitative and quantitative studies. In this paper, the role of facies and diagenesis processes on reservoir quality in the Cenomanian-Early Turonian Sarvak formation of SW of Iran was studied using 1504 samples from the core and a set of full suite logs from three wells. The depositional setting ranges from grain-rich reefal to lagoonal facies with grain-dominated and mud-dominated textures. Several diagenetic realms such as meteoric vadose, phreatic (vadose and marine) and mixing were identified based on petrographic observations. Compared to the muddominated facies of the Sarvak formation, the grain-dominated facies were intensely subjected to diagenetic processes. Furthermore, dissolution and neomorphism resulting from the subaerial exposure during meteoric diagenesis enhanced the reservoir quality, while further cementation, compaction and micritization have a negative impact on reservoir characteristics. The quantitative approaches show the eustatic sea-level rise in the Cenomanian-Turonian and the regional Turonian unconformity provide a textural and diagenetic pathway towards enhancing/reducing the reservoir quality. Reservoir properties are highly dependent on the sedimentary processes of the Rudist biostromes where secondary diagenetic agents are probably contributed through the selective leaching of aragonitic grains and matrix under the meteoric water environment.
      原文链接:
    • NSTL
    • Elsevier

    A laboratory study on fracture initiation and propagation of granite under cyclic-injection hydraulic fracturing

    Liu, YulongXu, TianfuYuan, YilongFeng, Bo...
    13页
    查看更多>>摘要：The abundant geothermal energy in hot dry rock (HDR) geothermal reservoirs is an attractive renewable energy resource with great potential. Cyclic injection in hydraulic fracturing has been proved to be a suitable way for the geothermal energy exploitation. However, the fracture initiation and propagation regimes induced by cyclic injection have been inadequately studied, and the fracturing optimization for HDR is often by experience. For this reason, true tri-axial hydraulic-fracturing tests were conducted to study the initiation and propagation of hydraulic fractures, while the specimens were subjected to the cyclic injection with different cycle time duration and injection rate. The results revealed that the initiation of hydraulic fracture was displayed as three basic patterns, and these fracture-initiation patterns were developed into two fracture geometries: simple fracture with only 2-4 strands and complex fracture network with >4 strands. The main reason for this difference is that the initiation and propagation of hydraulic fracture is controlled by the way of fluid circulation, and the cycle time duration and injection rate each played a different role in hydraulic fracturing. At a low injection rate, the initiation and propagation of hydraulic fractures under the high-frequency cycle (cycle time duration = 10 and 20 s) are mainly controlled by the change of injection pressure. Here, the hydraulic energy mainly acts on the rock near the well. The frequent change of injection pressure promotes the initiation of micro-fractures and forms a complex but short hydraulic fracture network. However, when high injection rate is subjected, too high and too low cycle frequencies (cycle time duration = 5 and 40 s) both tend to form a simple fracture, but the fracture has strong extension ability. With that, the similarity criterion of physical phenomena between the on-site prototype and the experimental model were discussed, and these lab-scale results were translated into the fracturing site of HDR.
      原文链接:
    • NSTL
    • Elsevier