首页期刊导航|Journal of Petroleum Science & Engineering
期刊信息/Journal information
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
正式出版
收录年代

    A Multi-1D modeling and hydrocarbon expulsion assessment of a sulfur-rich Thebes-S organofacies, Abu Rudeis-Sidri oil field, Eastern Egypt

    Ahmed Shaaban Ali AwadallaAli E. FaragOmar A. Hegab
    18页
    查看更多>>摘要：Most organic geochemical analyses focused on the source rock potentiality and ignored the contribution of numerical modeling to assess the generation potential of source rocks. The present study investigated the impact of the geologic evolution on thermal maturity, hydrocarbon generation potential of the Thebes-S organofacies to assess the hydrocarbon expulsion and exploration success of the Abu-Rudeis Sidri oil field. The Lower Eocene Limestone of the Thebes-S organofacies is considered as one of the most significant high sulfur-content source rocks within the central Gulf of Suez. The source rock intervals were depicted in five well locations using Passey et al.,1990 method (△logR) and published geochemical data. Then, the results of one-dimensional petroleum system modeling performed at multiple well locations were evaluated using the petroleum system modeling approach. The gas ratio analysis and star plot of n-alkanes in the ARM-5 well of Thebes-S and the previously studied Duwi-S organofacies were also used for genetical comparisons. The uncertainty analysis of the key input parameters of the Thebes-S organofacies was applied. The results of well-calibrated 1D models show differences in maturation histories of source rocks, and hence, variations in oil generation potential. The Thebes-S organofacies generated hydrocarbon at a lower maturity, in which the oil generation windows were reached at depths from 2025 to 2404 m TVDSS, whereas the gas generation windows were reached at depths from 2652 m to 2775 m TVDSS. Tectonically the central Gulf of Suez is characterized by three major rift phases: the Oligo-Miocene (25-23 Ma), the Lower Miocene (21-19 Ma), and the Mio-Pliocene (6-5.2 Ma). The source rock approached the main oil window in Pliocene (～4.42-1.95 Ma) and the thermogenic gas window at a later stage between 1.27 and 0.64 Ma. Besides the tectonic evolution, the burial depth was the major factor in the thermal maturation and hydrocarbon generation processes. Modeling results confirm insignificant hydrocarbon expulsion from the Thebes-S organofacies. This can be attributed to the following factors: (1) less overburden (2) low hydrocarbon saturation level; (3) late gas generation. These findings strengthen the idea that the oil was sourced from Duwi-S, rather than Thebes-S organofacies. This could suggest that the oil reservoirs from Thebes' organofacies in the study area are self-sourced.
      原文链接:
    • NSTL

    Geochemistry and origins of natural gas in the Hong-Che fault zone of the Junggar Basin, NW China

    Yong LiJungang LuXiangjun Liu
    15页
    查看更多>>摘要：The uplift zone adjacent to the sag is the dominant direction of natural gas migration and accumulation, and the multi-layer source rocks developed in the sag have laid a material foundation for natural gas accumulation However, owing to the deep burial and high drilling cost of the sag, drilling the source rocks in the sag is challenging, which severely restricts the fine gas-source correlation study of natural gas in the uplift zone. The Hong-Che fault zone is adjacent to the Shawan sag, the natural gas is of various types, and the origin and source of natural gas are unclear. The referential contrast research methods on multi-source and multi-period natural gas are absent, which hinders their subsequent exploration and development. In view of these problems, we analysed the pyrolysis gas of source rocks, along with its composition, including the light hydrocarbon and the carbon isotope of natural gas. The experimental results show that: (1) There are significant differences in the carbon isotopes of ethane in pyrolysis gas from different source rocks, which is one of the research bases of natural gas source analyses. (2) The natural gas in the region is mainly present as kerogen cracldng gas. (3) The natural gas in the study area is divided into five types. Type-I and type-II gases derived from the humic source rocks of the Carboniferous stratum and the Jiamuhe Formation, respectively. Type-IIIgas was sourced from the sapropelic source rocks of the Fengcheng Formation. Type-IV gas was originated from mixed source rocks of the Wuerhe Formation. Type-V gas was derived from the mixing of multiple sets of source rocks. (4) The south section of the Hong-Che fault zone has high gas production, and is a favourable exploration target for humic pure gas reservoirs. The slope area near the Shawan sag has better preservation conditions and is a favourable target area for subsequent natural gas exploration activities. These results lay the theoretical foundation for the evaluation and identification of the origins of multi-source and multi-period natural gas in complex areas.
      原文链接:
    • NSTL

    Sorptive permeability loss determined from strain-based analysis of tightly constrained experiments on shale

    Brandon SchwartzDerek Els worth
    9页
    查看更多>>摘要：We build a model to determine sorptive permeability loss from observed total permeability evolution by considering adsorption and poromechanical expansion as parallel processes. The model is cross verified with a separately derived strain-based model for sorptive permeability evolution. Both models are compared to laboratory data and are shown to have excellent agreement. We isolate the sorptive strain from the total strain measured during serial injection of sorptive then non-sorptive gas species. Our model predicts that injection of a non-sorptive gas into a shale saturated with a sorptive gas causes permeability to approximately double in both the bedding-parallel and bedding-perpendicular directions. We preform nitrogen floods at constant stress, pore pressure, and temperature to observe tire sorptive permeability recovery absent other confounding effects. We confirm that in shales the component of permeability evolution due to sorptive swelling can be isolated from effective stress effects. Laboratory results show a 206% and a 234% permeability increase in the bedding-perpendicular and bedding-parallel directions, respectively, as a result of nitrogen flooding. This counters and indeed dominates over any sorptive permeability loss that despite a modest fraction of organic material (～1-2%) is amplified by the low pore density. We find that sorptive permeability evolution in shales is controlled by the sorptive strain, pore density, and pore geometry.
      原文链接:
    • NSTL

    Pore structure analysis and permeability prediction of shale oil reservoirs with HPMI and NMR: A case study of the Permian Lucaogou Formation in the Jimsar Sag, Junggar Basin, NW China

    Fuyong WangLu Wang
    14页
    查看更多>>摘要：The pore structure characteristics and formation permeability are important reservoir information for the development of shale oil. The pore structures of the shale oil formation in the Lucaogou Formation in the Jimsar Sag are characterized with high-pressure mercury injection (HPMI), nuclear magnetic resonance (NMR), and fractal theory. The capillary bundle model, geometric model, and wetting phase model are used to obtain the fractal dimension of the capillary pressure curve. Among them, D_(f1) from the capillary bundle model is between 2.1937 and 3.4131, D_(f2) from the geometric model is within a range of 1.0414-3.575, and D_(f3) from the wetting phase model is from 0.5691 to 2.7047. For NMR spectra, the pore space is divided into micropores, mesopores, and macropores based on the peak value of the NMR T2 spectra, and the fractal dimension of different pore types is calculated, where D_(fmi) is from 1.564 to 2.301, D_(fme) is in a range from 2.082 to 2.941, and D_(fma) is between 2.831 and 2.991. The relationships between the fractal dimension and petrophysical parameters are analyzed, and the results indicate that among the three types of models, the fractal dimension of the capillary bundle model has the highest correlation with the core petrophysical parameters. Therefore, it is recommended to use the capillary bundle model to evaluate the fractal characteristics of pore structures. In particular, the fractal dimension is positively correlated with the throat coefficient and negatively correlated with the size of the pore throat. In contrast, the fractal dimension of NMR has a poor correlation with core petrophysical parameters. There is no obvious correlation between the fractal dimension of micropores and petrophysical parameters, while the fractal dimension of mesopores and macropores is only correlated with the throat-sorting coefficient, and the correlation coefficient is less than 0.15. Thus, the fractal dimension from NMR data is not suitable for studying the fractal characteristics of shale oil cores in the Lucaogou Formation. In addition, we predicted the permeability of shale cores using the Swanson model, Pittman model, and Winland model. The permeability prediction results show that the Swanson model has the greatest accuracy, followed by the Winland model. Among them, the accuracy index (ACI) of the Swanson model is 0.901, and the ACI of the Winland model is between 0.483 and 0.897. The permeability prediction by the Pittman model is poorest among these three models.
      原文链接:
    • NSTL

    Semi-analytical modeling of transient pressure behaviour for a multifractured horizontal well in a gas reservoir with a complex fracture network by considering effects of slippage, stress-sensitivity, and gas adsorption/desorption

    Yunhao ZhangYurong JinDaoyong Yang
    16页
    查看更多>>摘要：A semi-analytical technique has been developed, validated, and applied to quantify the pressure behaviour of a multifractured horizontal well (MFHW) in a gas reservoir with discrete fracture networks and an arbitrary boundary. Considering stress-sensitivity and the slippage effect in the matrix subsystem, a pseudo-pressure is incorporated into the gas flow equations. To weaken the strong nonlinearity from such a combined effect, the dual-reciprocity boundary element method (DRBEM) is applied to efficiently and effectively linearize the governing equations by replacing the nonlinear function with a series of particular solutions. Comparing with the boundary element method (BEM), not only can the DRBEM be used to obtain the accurate solution in any space and time domains, but also it is flexible to deal with the nonlinearity restriction in the governing equations. The finite volume method (FVM) is then adopted to simulate gas flow behaviour in the fracture subsystem with different fracture geometries. Not only can the proposed model be applied to a complex fracture network and operating schedules, but also capture complex gas flow behaviour including the Langmuir sorption, slippage effect, and stress-sensitive effect in a gas reservoir with a discrete fracture network and an arbitrary boundary, The mathematical formulations have been validated and then extended to field applications. A strong stress-sensitive effect is found to result in a large pressure drop and offset the permeability-enhancing effect from the slippage effect. In addition, a decrease in pressure drop derived from gas desorption would restrict the stress-sensitive effect. Furthermore, it can be found that each individual factor imposes a significant impact on the linear flow and boundary dominated flow regimes. On the basis of a mutual interference, the combined effect (i. e., stress-sensitivity, slippage effect, and gas adsorption/desorption) may be weaker than that of each individual factor. In the late boundary-dominated flow regime, the effect of boundary shape becomes more obvious on the pressure distribution curves since the pressure wave would reach the boundaries near fractures within a relatively short time.
      原文链接:
    • NSTL

    Quantitative experimental study on the rule of fluid flow and its influencing factors in hydraulic fractures

    Ming LiJianchun GuoTao Zhang
    32页
    查看更多>>摘要：Hydraulic fracturing has become a necessary tool for developing unconvendonal oil and gas resources. The goal is to create fractures in the subsurface and transport proppant from the surface into the subsurface fractures, which is accomplished by pumping a high-pressure fluid to open formation and using the energy of fluid to extend the fractures. Then, the fluid carries the proppant into the fracture and fills it. Therefore, the fluid plays a crucial role in the fracturing process, and the rule of fluid flow in the fracture affects the effectiveness of hydraulic fracturing. Based on this, this paper establishes a quantitative experimental device to simulate the process of fluid being injected into a fracture. The device achieves the first acquisition of the information of the flow field in the fracture by introducing the technology of particle image velocimetry (PIV). Our study found that the fluid flows through the perforation tunnel will occur obvious jet phenomenon thus causing the formation of a large number of vortices in the flow field near the entrance of fracture, and the turbulence of the flow field is high and the fluid flow is complex. As the fluid flows toward the distal end of the primary fracture, the vortices in the flow field disappear, and the flow field gradually becomes stable and the fluid flow is regular. And according to the characteristics of the distribution of the vorticity of the fluid in the primary fracture, we divide the flow field into three main characteristic areas, namely, the jet vortex zone, the turbulent transition zone and the stable development zone. When the fluid flows to the secondary fracture, vortices are formed and there is a obvious area of disturbance which affects the flow of fluid. In addition, we analyzed the effects of pump rate, viscosity, and perforation location on each area in the fracture and obtained the main control factors for each zone. This study provides the first systematic analysis of the law of flow in the fracture from the perspective of flow field, which profoundly reveals the rule of fluid flow in the process of hydraulic fracturing. This study provides theoretical guidance for the design and optimization of fracturing schemes, and provides reference significance for the microscopic study of flow in the fracture.
      原文链接:
    • NSTL

    A fully coupled multidomain and multiphysics model considering stimulation patterns and thermal effects for evaluation of coalbed methane (CBM) extraction

    Wai LiJishan LiuJie Zeng
    25页
    查看更多>>摘要：A deep understanding of the process of coalbed methane (CBM) extraction is of significance for both the un-conventional energy supply and mine safety. The effects of stimulation patterns and thermal effects (including thermal shrinkage, non-isothermal sorption, and gas density change) significantly affect the CBM extraction process. Although thermal effects on CBM extraction have been investigated in previous studies, these effect have not been coupled with stimulation patterns, leading to an insufficient evaluation accuracy of previous models and a limited understanding of gas extraction in stimulated CBM reservoirs. This study developed a multidomain and multiphysics (thermal-hydraulic-mechanical, THM) model to fully couple different physical processes (including gas flow, coal deformation, gas desorption, and heat transfer) within a CBM reservoir framework considering various stimulation patterns to improve the simulation accuracy and obtain insights into CBM extraction. Three domains with distinct properties, i.e., the stimulated reservoir domain (SRD), non-stimulated reservoir domain (NSRD), and radial primary fracture (PF), were integrated into the CBM reservoir model to characterize the stimulation pattern. A group of partial differential equations (PDEs) was derived to characterize CBM transport within each domain and across different domain boundaries. A stimulated coalbed was defined as an assembly of three interacting porous media: coal matrix, continuous fractures (CF), and PF. The matrix and CF constituted a dual-porosity dual-permeability system, while the PF was simplified as a 1-D fractured medium. The finite element method (FEM) was employed to numerically solve the above PDEs. The proposed model was verified against two sets of field-measured CBM production data and compared to three previously published numerical models to reveal its advantage. The verified model was applied to investigate multidomain effects of stimulation treatment and evaluate the thermal effects of gas depletion on gas extraction in stimulated CBM reservoirs. The simulation results suggested (1) that the distinct properties of the different domains result in different permeability evolutions, which in turn influences CBM production; (2) that increasing the fracture complexity, enlarging the SRD size, and improving the SRD permeability with suitable stimulation techniques constitute effective approaches to enhance the CBM recovery; and (3) that ignoring thermal effects in CBM extraction can either overestimate or underestimate production, which mainly depends on die net effects of the thermal shrinkage strain and non-isothermal sorption during different production periods.
      原文链接:
    • NSTL

    Oxidation of heavy crude oils under reservoir conditions: Influence of catalysts and the gas phase

    A.A. AkhmadiyarovI.T. RakipovR.Z. Salikhov
    6页
    查看更多>>摘要：In this work the influence of catalysts on in situ combustion process of heavy crude oil has been studied. The heavy crude oil from Russia (Ashal'cha field) oil field was used. The research on oxidation was performed using accelerating rate calorimetry (ARC). The effect of type of metal oxide (NiO, Co3O4, Fe3O4) on catalytic oxidation process of crude oil at conditions close to reservoir's pressure and temperature was investigated. The impact of catalyst particle size on oxidation process of crude oil has been revealed. The composition of gas mixture has been shown to alter the activity of the catalyst in oxidation process. The correlation between type of catalyst as well as the composition of gas phase and kinetic parameters of reaction was found. Arrhenius kinetic parameters were derived from experimental data of crude oil oxidation.
      原文链接:
    • NSTL

    Characterization of crude oil interfacial material by high-resolution mass spectrometry

    Jianxun WuHan LiQianhui Zhao
    7页
    查看更多>>摘要：Petroleum crude is known to contain natural interfacial material (IM) which promotes the formation of stable emulsions. Characterization of the IM is of great interest to the petroleum industry, which allows a better formulation of demulsifiers for the separation of oil-water mixtures in petroleum operations. In this study, IMs in crude oils from Xinjiang, Jianghan, and Daqing, China were separated by the wet silica adsorption method. High-resolution Orbitrap mass spectrometry combined with high energy collisional dissociation was used to reveal the functional groups of separated IMs. The results showed that compound classes of IMs were predominantly O4 (compounds with 4 oxygen atoms in each molecule), O3S1, O4S1, and N1O2. The O4 class species were dicarboxylic acids and their corresponding salts; O3S1 class species were sulfonates; O4S1 class species were either sulfonates or sulfates; and N1O2 class species were amphipathic molecules with both carboxylic and pyridyl functional groups. The composition of IMs are largely different among various crude oils. Most IMs were naturally occurring compounds and some were artificially synthesized chemicals that were introduced in the oil production operation.
      原文链接:
    • NSTL

    A dual porous and fractures medium CBM numerical model development and analysis

    Peitao LiQuansheng Liu
    15页
    查看更多>>摘要：The drilling unloading will produce fractures in the plastic zone around the borehole. However, the fracture is the main seepage channel of coalbed methane. It is not appropriate to ignore the influence of fractures on gas flow, especially in the plastic zone. According to the stress redistribution characteristics after unloading, the fracture field in the plastic zone is considered in the coalbed methane numerical model. A two-dimensional random fracture field is introduced via the Monte Carlo method in the plastic zone, which is based on the central limit theory and box muller method. A dual porous and fracture medium numerical model is proposed, which considers not only gas adsorption and desorption, but also fracture distribution and creep deformation. A comparison between the proposed model and the single porous medium numerical model is carried. The results show that the proposed model can reflect not only the evolution characteristics of gas flow but also the anisotropic influence of fracture. It further explains the evolution mechanism and distribution law of gas flow. Finally, the influence of fracture field parameters (fracture density, fracture length, and fracture width) on gas flow is discussed, which is expected to provide a theoretical basis and reference for the development and research of coalbed methane.
      原文链接:
    • NSTL