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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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    Reservoir rock typing and electrofacies characterization by integrating petrophysical properties and core data in the Bangestan reservoir of the Gachsaran oilfield, the Zagros basin, Iran

    Maldar, RaminRanjbar-Karami, RasoulBehdad, AliBagherzadeh, Samira...
    24页
    查看更多>>摘要：The super-giant Gachsaran oilfield is situated in the Dezful Embayment of the Zagros basin. The main goal of this study is to characterize the reservoir rock types by integrating the available geological and petrophysical studies in the Bangestan reservoir along with adopting a way to figure out the optimal number of electrofacies codes. At the first step, the types of porosity and geological microfacies were studied by using 163 thin sections from the core samples. The microscopic studies revealed that fractures and intraparticle interstices are the most common porosities types. Also, they resulted in the identification of 4 microfacies in the Bangestan reservoir. In a complementary study, the Velocity-Deviation Log (VDL) was employed to determine the dominant pore types. By comparison of the VDL values and thin section studies' results, it was deduced that high micro-porosities along with hairline fractures are the predominant pore types of the Bangestan reservoir. At the second step, the optimal number of reservoir rock types (RRT) was determined by using the concept of hydraulic flow units. Thus, six flow units were distinguished by utilizing the Flow Zone Indicator (FZI) method in which the reservoir properties were improved from RRT-1 toward RRT-6. In the third step, the data clustering analysis, known as the electrofacies analysis, was employed to identify the accurate petrophysical rock types based on the meaningful segregation of capillary pressure curves within each electrofacies code and then propagated in non-cored intervals and boreholes. In this research, an optimal number of 7 electrofacies were identified by employing the petrophysical curves including effective porosity (PHIE), bulk density (RHOB), sonic (DT), and water saturation (SWE), along with considering the number of reservoir rock types and the defined geological microfacies, as well as the relations of the available capillary pressure data within different electrofacies codes. The validity of the proposed electrofacies was scrutinized through petrophysical results including shale volume, water saturation, and effective porosity. In the end, the electrofacies codes were compared to the defined geological microfacies. Finally, this study shows that the correlation of capillary pressure data and electrofacies codes can be resulted in figuring out the optimal number of electrofacies codes. In addition, by trying to honor the link between geological microfacies, capillary pressure, and petrophysical curves, the constructed electrofacies model, as a suitable practical integrated rock typing method, can be the foundation of property modeling, guide the spatial distribution of reservoir properties in the 3D model, aids to model the dynamics of fluid flow more realistically in reservoir simulation phase, and ultimately be beneficial for further development and production decisions in the Bangestan reservoir of the Gachsaran oilfield.
      原文链接:
    • NSTL
    • Elsevier

    Monitoring of microscopic behavior of nano-enhanced colloidal gas aphron in fractured and un-fractured non-uniform porous medium

    Tabzar, AmirGhazanfari, Mohammad Hossein
    13页
    查看更多>>摘要：The present article aimed to examine the pore-scale examination of a fluid capability to block pores and fractures deduced by return permeability and the blocking ability of a novel lightweight Colloidal Gas Aphron Nano-Fluid (CGANF) in heterogeneous fractured/un-fractured porous medium. Silica (S) and fumed silica (FS) nanoparticles, Sodium Dodecyl Sulfate (SDS) anionic surfactant, and Xanthan Gum (XG) bio-polymer were employed for following up CGANF bubbles' movements in incongruous micro-models' inclusive crack. The transparent nature of the glass micro-model provides an intuition into the lenticular behavior of CGANF bubbles in the heterogeneous porous media. Differential pressure analysis through porous media during experiments demonstrated that opposition to the stream of CGANF bubbles increased as more CGANF fluid was injected. Also, the lamella division mechanism generated more small bubbles resulting in increasing differential pressure across porous micro models. Contrasted to bigger CGANF bubbles, smaller CGANF bubbles had lesser movability. Therefore, they were key factors for blocking pores and throats of porous media and changed the orientation of bigger bubbles in cracks toward the matrix. Observations revealed that CGANF micron-bubbles built up through the porous media could set up an impressive snag to control loss of filtrate, and permeability of models was reverted almost to its primary permeability when saturation fluid was reinjected into micro-models. For the detailed analysis in this study, the maximum percentages of reverted permeability for fractured and un-fractured non-uniformed micro models were attained 91.81% and 90.70%, respectively. Also, by increasing XG concentrations from 0.286 to 0.571% w/v, return permeability percentage increased from 84.4% to 87.4%. There was an optimum concentration of nanoparticles at 0.0571% w/v of silica and fumed silica, and consequently, returned permeability and infusion pressure of CGANF fluid reached their maximum values. Moreover, the stability of the CGANF fluid increased to 8.15% and 12.6% by adding silica and fumed silica nanoparticles, respectively, to the CGA fluid formulation without nanoparticles. This article presents a novel insight into porous media for analyzing blockage capability and controlling porous media damage created via CGANF-based fluids in non-uniformed environments.
      原文链接:
    • NSTL
    • Elsevier

    Petrological and organic geochemical characteristics of the Permian Lucaogou Formation in the Jimsar Sag, Junggar Basin, NW China: Implications on the relationship between hydrocarbon accumulation and volcanic-hydrothermal activities

    Meng, ZiyuanLiu, YiqunJiao, XinMa, Litao...
    17页
    查看更多>>摘要：The coupling relationship between volcanic-hydrothermal activities and hydrocarbon generation has been a common understanding in recent years. However, there is a lack of theoretical and practical guidance in the application hydrocarbon production. The fine-grained sedimentary rocks of the middle Permian Lucaogou Formation in the Jimsar Sag in the Junggar Basin, NW China, are critical source rocks and have been simplify regarded as a mudrocks for target for tight oil exploration. Recently studies show that rocks were deposited in an intracontinental lacustrine environment with multiple volcanic-hydrothermal activities. Their complex micro scale lithological characteristics restrict the understanding and further exploration and development of tight oil. Hence, this study focuses on the detailed lithological and their organic geochemical characteristics of the Lucaogou Formation using microscopic thin-section observation, scanning electron microscopy, X-ray diffraction, Rock-Eval, saturated hydrocarbon chromatography and mass spectrometry. The following key conclusions were obtained. First, the massive mudrocks are sub-divided into lithofacies for hydrocarbon generation, including tuffaceous shale, calcareous shale and dolomitic shale, and, microinterval reservoirs, including dolostone and sedimentary tuff. Second, the origins of organic matter in Lucaogou Formation were mainly plankton, bacteria with minor of land plants. The depositional environment is high salinity and anoxic conditions. Materials derived from volcanic-hydrothermal activities, lacustrine precipitation, and terrestrial transportation mixed with various proportions to form this formation. Third, a mixture of carbonate minerals, felsic minerals and clay minerals is the best source rock, and the higher the mixture, the better. This research not only provides insight into the influence of volcanic-hydrothermal activities on lithology and organic matter enrichment, but also providing a potential scheme for the tight oil exploration and development in similar rifted geological settings.
      原文链接:
    • NSTL
    • Elsevier

    A novel hybrid recurrent convolutional network for surrogate modeling of history matching and uncertainty quantification

    Ma, XiaopengZhang, KaiZhang, JindingWang, Yanzhong...
    14页
    查看更多>>摘要：Automatic history matching (AHM) has been widely studied in petroleum engineering due to it can provide reliable numerical models for reservoir development and management. However, AHM is still a challenging problem because it usually involves running a great deal of time-consuming numerical simulations during the solving process. To address this issue, this article studies a hybrid recurrent convolutional network (HRCN) model for surrogate modeling of numerical simulation used in AHM. The HRCN model is end-to-end trainable for predicting the well production data of high-dimensional parameter fields. In HRCN, a convolutional neural network (CNN) is first developed to learn the high-level spatial feature representations of the input parameter fields. Following that, a recurrent neural network (RNN) is constructed with the purpose of modeling complex temporal dynamics and predicting the production data. In addition, given that the fluctuations of production data are influenced by well control measures, the well control parameters are used as auxiliary inputs of RNN. Moreover, the proposed surrogate model is incorporated into a multimodal estimation of distribution algorithm (MEDA) to formulate a novel surrogate-based AHM workflow. The numerical studies performed on a 2D and a 3D reservoir model illustrate the performance of the proposed surrogate model and history matching workflow. Compared with the MEDA using only numerical simulations, the surrogate-based AHM workflow significantly reduces the computational cost.
      原文链接:
    • NSTL
    • Elsevier

    Rock cutting mechanism of special-shaped PDC cutter in heterogeneous granite formation

    Zhu, XiaohuaLuo, YunxuLiu, WeijiYang, Feilong...
    16页
    查看更多>>摘要：Special-shaped Polycrystalline Diamond Compact (PDC) cutters show the superiority for improving rate of penetration (ROP) in hard abrasive formation drilling. However, few attentions have been paid on its geometric design and rock cutting mechanism. To deepen the understanding of special-shaped PDC (SPDC) cutter's rock-breaking mechanisms and provide a certain reference for the selection and application of SPDC cutters in the specific target formation, this paper firstly proposes two new principles (loading performance (LP) and cutting performance (CP)) as well as their evaluation indexes for evaluating the cutting process of cutters from the relationship between geometry, aggressiveness, stress state, working life, and rock cutting efficiency of SPDC cutters. Then, using gray-white granite as the research object, the finite element heterogeneous granite model, whose relative percentage error of all calibration quantities with experiment are less than 7%, based on Voronoi tessellation and the granite cutting model of 10 types cutters under confining pressure are established. Finally, the cutting results are discussed, and the CP of all cutters are evaluated. It's found that the ductile-brittle failure mode in the removal area and the influence region of cutting process determine the rock failure mode of SPDC cutters. The confining pressure has an inhibitory effect on rock cutting efficiency, it's because the high confining pressure leads to ductile dominated failure mode in removal area. The confining pressure weakens the LP and CP of cutters, but has no obvious effect on their stress distribution state. With the increasing of confining pressure, "ductile-plastic stick-slip cutting" effect is produced in the removal area. The conical-shaped cutter (whose CP coefficient is 4.3 x 10(-3) - 5.4 x 10(-3) N-1) and saddle-shaped cutter (whose CP coefficient is 3.4 x 10(-3) - 4.8 x 10(-3) N-1) are the optimal selection for heterogeneous granite formation. On the contrary, the three-blade cutter and cusp-shaped cutter are unsuitable for heterogeneous granite formation. This research leads to an enhanced understanding of rock-breaking mechanisms of SPDC cutters, and provides the basis to select of SPDC cutters for the specific target formation.
      原文链接:
    • NSTL
    • Elsevier

    Enhanced oil recovery with D-Limonene diluted in brine

    Gaitan Espinosa, MauricioZavala-Arriaga, MercedesRamirez-Gonzalez, Patsy, V
    9页
    查看更多>>摘要：D-Limonene, a compound consisting of terpenes in its dextrogyrous form, is commonly used as a degreaser, hydrocarbon waste cleaner and as a sand oil separator. In this work, the use of this chemical is proposed as an alternative for enhanced oil recovery (EOR). Two oils from the southeast basin of Mexico (one medium and one extra-heavy oil) were tested for viscosity reduction with D-Limonene. The viscosity of the heavier oil @25 degrees C is 117,000 cP. The addition of 5% D-Limonene decreased the viscosity to 55,000 cP at same conditions, which corresponds to 53% reduction. The addition of D-Limonene also reduced the percentage of asphaltenes and paraffins in oil and increased the percentage of aromatics and resins (according to SARA analysis). D-Limonene was diluted (3% v/v) in brine and EOR tests were performed on a bioclastic sandstone rock with the medium oil. The rock has a helium permeability of 2.6 mD, slightly higher than the carbonated rocks, both characteristic of the Mexican Republic. The rock was characterized by scanning electron microscopy (SEM), porosimetry and Xray diffraction. Contact angles were measured to know the humectability of rock with respect to oil, brine and DLimonene. Coreflooding tests were carried out in a CoreFlood equipment at 50 degrees C and an average of 62.6% oil recovery with 3% D-Limonene diluted in brine was achieved. It should be noted that D-Limonene is a biodegradable and harmless product.
      原文链接:
    • NSTL
    • Elsevier

    Cementing displacement efficiency analysis in long horizontal wells: An optimized numerical simulation approach (vol 208, 109393, 2022)

    Hu, HanLiang, XueZhang, MengnanFan, Honghai...
    1页
      原文链接:
    • NSTL
    • Elsevier

    Multi-solution well placement optimization using ensemble learning of surrogate models

    Salehian, MohammadSefat, Morteza HaghighatMuradov, Khafiz
    15页
    查看更多>>摘要：Well location optimization aims to maximize the economic profit of oil and gas field development while respecting various constraints. The limitations of the currently available well placement optimization workflows are their 1) high computational requirements, which makes them inappropriate for full-field applications where a large number of wells have to be optimized using a computationally expensive simulation model; and 2) providing a single optimal solution, whereas on-site operational problems often add unforeseen constraints that result in adjustments to this optimal, inflexible scenario degrading its value. This study presents a multi-solution, surrogate models (SMs)-assisted optimization framework to deliver diverse, close-to-optimum well placement scenarios at a reasonable computational cost. Simultaneous Perturbation Stochastic Approximation (SPSA) algorithm is used as the optimizer while diversity in optimal solutions is achieved by multiple, parallel runs of the optimizer with different starting points. Convolutional Neural Network (CNN) is used as the SM, to partly substitute the computationally expensive reservoir model runs during the optimization process. A new, adjusted Latin Hypercube Sampling (aLHS) procedure is developed to generate initial training datasets with diverse well placement scenarios while respecting reservoir boundaries and well spacing constraints. An ensemble of CNNs is pre-trained using the generated dataset to enhance the robustness of the surrogate modeling as well as to allow estimation of the SM's prediction quality for new data points. The ensemble of CNNs is adaptively updated during the optimization process using selected new data points, to improve the SM's prediction accuracy. To the best of our knowledge, this is the first application of ensemble learning strategy to a well placement optimization problem. The added value of the framework is demonstrated by comparing three optimization approaches on the Brugge and Egg field benchmark case studies. The approaches are 1) 'no SM': using the actual reservoir model only, 2) 'Offline SM': the optimization is performed using SM-only that is pre-trained using initial training datasets generated by the actual reservoir model, and 3) 'Online SM': pre-trained CNNs are adaptively updated during the optimization process using new datasets generated using the actual reservoir model. The surrogate-assisted optimization approach substantially reduced the computation time, while a greater objective value was achieved by employing the adaptive learning strategy due to the enhanced prediction accuracy of the SMs. Multiple diverse solutions were obtained with different well locations but close-to-optimum objective values, which allows a more efficient exploration of the search space at a significantly reduced computational cost. The presented workflow integrates critical challenges that are correlated, yet often addressed independently, providing the much-required operational flexibility and computational efficiency to field operators when selecting from the optimal well placement scenarios.
      原文链接:
    • NSTL
    • Elsevier

    Prevention of hematite settling using perlite in water-based drilling fluid

    Basfar, SalemAl Jaberi, JaberElkatatny, SalaheldinBageri, Badr S....
    8页
    查看更多>>摘要：The stability of the weighting materials in the high-density water-based drilling fluid was remarked as a serious issue to be controlled. It can cause several problems including formation fracturing, circulation loss, well control issues, etc. The usage of an anti-sagging chemical as a drilling additive is one of the sagging mitigation methods. In this study, amorphous volcanic alumina silicate (perlite) was evaluated as an anti-sag additive for hematite water-based drilling fluid. Several experiments were conducted to assess the perlite efficiency including static and dynamic sag test, mud properties measurements such as filtration behavior, filter cake properties, rheological and viscoelastic behavior. The tests were conducted at elevated temperature (250 degrees F). Perlite concentration was varied from 0, 1, 2, 3, and 4 lb/bbl. The obtained results showed that the loaded perlite was able to improve the mud stability and eliminate the sagging under static and dynamic issues at an optimum concentration of 4 1b/bb1. In term of filtration properties, there was an obvious improvement that could be observed through the reduction of filtration volume with 50% and filter cake thickness. In addition, the perlite contacting drilling fluid was able to form a thin and dense filter cake layer. The filter cake porosity and permeability were decreased by 24% and 68%, respectively. The rheological and viscoelastic behaviors were improved as well by the addition of perlite.
      原文链接:
    • NSTL
    • Elsevier

    Prediction model of high-voltage pulse boring rock-breaking process and intelligent identification of model parameters

    Li, ChangpingYang, Wenjian
    10页
    查看更多>>摘要：High-voltage electro-pulse boring (EPB) is featured in high drilling efficiency, low energy consumption and low drilling cost. Firstly, based on the energy conservation law, an EPB process prediction model is established, which is composed of EPB discharge rock-breaking circuit sub-model based on distributed capacitance and timevarying resistance, and shock wave sub-model. The time delay characteristics of a gas discharge switch and the distributed capacitance in a discharge circuit are taken into account in the EPB discharge rock-breaking circuit sub-model to make it closer to the actual discharge circuit. Meanwhile, the model can predict the real-time process parameters such as discharge voltage, power, and energy in the EPB process. The shock wave submodel can predict the plasma channel radius, shock wave and other process parameters. Secondly, an EPB test system is developed to realize EPB in different rock samples and the detection of electric parameters. A singular value decomposition (SVD) filtering algorithm is developed to extract the useful current signals in the environment with strong noise and interference. Thirdly, based on genetic algorithm (GA) and particle swarm optimization (PSO), an improved hybrid intelligent algorithm is proposed by improving the fitness function and inertia weight. According to the electric parameter curves of the EPB in different rock samples, the parameters of EPB discharge rock-breaking circuit sub-model are identified by the improved PSO-GA. After this algorithm is adopted to identify the model parameters, the current curve is fitted. Compared with other identification hybrid algorithms, the average convergence speed of the improved PSO-GA algorithm is increased by 50.1%, and the average percentage of parameter identification error is reduced by 23.9%. Finally, according to the identified model parameters, the real-time parameters of the shock wave are obtained in the process of the high-voltage EPB. The mechanism of high-voltage EPB process is analyzed and summarized. This research is able to predict the process parameters of high-voltage EPB rock-breaking and summarize the law of high-voltage EPB rockbreaking. Therefore, this research is greatly important to guide the selection of EPB process parameters and improve the drilling efficiency.
      原文链接:
    • NSTL
    • Elsevier