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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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    Geochemistry of formation waters and crude oils in the Shulu Sag, Bohai Bay Basin, NE-China, to assess quality and accumulation of hydrocarbons

    Cai, ChuanQiu, NanshengLiu, NianLi, Zhenming...
    18页
    查看更多>>摘要：Geochemical fingerprinting of formation waters and hydrocarbons can be utilized to track the migration, accumulation, and preservation of hydrocarbons. The present case study from the Shulu Sag, Bohai Bay Basin, NE-China analyzes the origin of the formation waters and the relationship between water chemistry and hydrocarbon preservation by combining the geochemical characteristics of formation waters and crude oils. There are three geochemical groups of formation waters with different origins, which represent different hydrodynamic environments and hydrocarbon preservation conditions. Group 1 waters are related to meteoric water with the lowest total dissolved solids (TDS), gamma(Cl-Na)/gamma Mg and the highest gamma Na/gamma Cl, representing an open environment with poor hydrocarbon preservation conditions, accompanied by super heavy oils. Group 3 waters are connate water with the highest TDS, gamma(Cl-Na)/gamma Mg and the lowest gamma Na/gamma Cl, representing a closed environment with the best hydrocarbon preservation conditions, accompanied by light oils. Group 2 waters are intermediate between Group 1 and Group 3 waters, representing a semi-open environment with intermediate hydrocarbon preservation conditions, accompanied by light, medium, and heavy oils. The clear corresponding relationship between oil quality and associated water type shows that water chemistry significantly affects the oil quality and accumulation in the Shulu Sag through secondary changes. Biodegradation is the dominant effect in the strata above 2100 m. Water washing is dominant in the depth range of 2100-3400 m, and there are no noticeable secondary changes in the strata below 3400 m. A model for the origin, evolution, and flow of formation waters in the Shulu Sag is established to analyze the hydrocarbon accumulation process. Meteoric waters flow into the buried hills from Ningjin Uplift as a result of gravity flow, resulting in modification of oil composition, destruction of the oil reservoirs, and the formation of Group 1 waters. During the hydrocarbon charging, the centrifugal flow driven by overpressure flows in two directions from the source rocks, one is to the western slope and mixes with meteoric waters to form Group 2 waters and heavy oil reservoirs, and the other is to the paleo-uplift to form Group 2 and Group 3 waters and light oil reservoirs. Water chemistry is sensitive to the hydrodynamic environment change and can be an important reference for oil and gas exploration. Buried hills with Group 3 waters should be the highest priority for further exploration, whose oil reservoirs are dominated by light oil with high commercial value. Although the oil quality is poor, buried hills with Group 2 waters in the slope can be secondary targets. In comparison, the buried hills with Group 1 waters should be avoided for oil and gas exploration. The geochemistry of formation waters helps understand the origin and evolution of formation waters, predict oil quality and distribution, and further aids oil and gas exploration.
      原文链接:
    • NSTL
    • Elsevier

    Effect of rheology and solids concentration on hydrocyclones performance: A study involving the design variables of an optimized hydrocyclone

    Goncalves, Suelen MaraUllmann, GregoriMorimoto, Murilo Guimaraesde Souza Barrozo, Marcos Antonio...
    13页
    查看更多>>摘要：Despite several advances in the field of separations in hydrocyclones, achieving high separation efficiency in these devices when operating with concentrated non-Newtonian suspensions is still a challenge, and any improvement in this aspect can be a significant contribution. Thus, the objective of this study was to evaluate the behavior of a hydrocyclone operating with concentrated pseudoplastic suspensions. The device used in this study was the Maximum Overall Efficiency Hydrocyclone (MOEH), which is the result of a geometric optimization study developed by our research group whose objective was to obtain a hydrocyclone geometry that led to high separation efficiencies. The polymer carboxymethyl cellulose (CMC) was used as a rheological modulator at different concentrations. Changing the concentration of CMC in the suspension from 0.2 wt% to 1.0 wt%, it was observed reductions of 27% and 23% for the Euler number and overall efficiency of the MOEH hydrocyclone, respectively. When operating with dilute pseudoplastic suspensions (CCMC < 0.6 wt%), the drop in the separation performance could be mitigated with appropriate increments in the dimensions of the underflow diameter and reductions in the vortex finder length. Above a concentration of 0.8 wt% CMC the hydrocyclone operated as a stream splitter, with reduced efficiency of less than 2%, and the modifications in the design variables were not sufficient to reverse the detrimental effect of the increased slurry viscosity. The results obtained in this study show the relevant effect of non-Newtonian fluids in the functioning of hydrocyclones and the importance of the correct choice of geometric configurations and operating conditions to reduce the impact of the rheology in the separation performance.
      原文链接:
    • NSTL
    • Elsevier

    Efficient application of stochastic Discrete Well Affinity (DiWA) proxy model with adjoint gradients for production forecast

    Tian, XiaomingVoskov, Denis
    14页
    查看更多>>摘要：In this paper, we describe adjoint gradient formulation for the Operator-Based Linearization modeling approach. Adjoint gradients are implemented in Delft Advanced Research Terra Simulator (DARTS) framework and applied for history matching using a proxy methodology. Due to the application of adjoint gradients, the computational efficiency of the discrete well affinity (DiWA) proxy model for production forecast is significantly improved. That allows us to derive several important extensions. The proxy methodology is further extended and validated for 3D three-phase black-oil problems. The results show that the gradient-based regression can provide good history matching and reconstruct a true petrophysical characterization when the initial guess is generated based on highly reliable geological information. For cases with a limited or not sufficient geological characterization, an efficient stochastic application of DiWA proxy model is proposed. This approach consists of massive sampling procedures for collecting different realizations based on high-fidelity statistics with filtering. These realizations are generated stochastically because they are not conditioned to any production information but the basic geological statistics of the reservoir. The trained DiWA proxy model demonstrates a small deviation between the model response and the observation data. When applying the refined DiWA model for the training, the error between the model response and observation data can be further reduced. The forecast based on the trained model has slightly larger variability but the deviation is still reasonable. The enhanced DiWA methodology presents an efficient and robust technique for creating an ensemble of stochastic proxy models that can be used in production forecast, flow diagnostic, and optimization.
      原文链接:
    • NSTL
    • Elsevier

    Permian and Triassic hydrocarbon migration and accumulation in the Cainan area, Junggar Basin, China

    Song, JianyangChen, TaoZhang, Jinliang
    20页
    查看更多>>摘要：Gas Chromatography-Mass Spectrometer (GC-MS), chloroform asphalt "A", and carbon isotope measurements were used to determine hydrocarbon migration pathways. This study focused on hydrocarbon migration pathways and accumulation distribution in the Wucaiwan region, Junggar Basin, China. The biometric parameters were used to compare oil sources. Type and distribution characteristics of natural gas were determined in order to study the different strata. Quantitative grain fluorescence (QGF) and quantitative grain fluorescence on extract (QGF-E) were analyzed to determine the hydrocarbon migration and charging periods. Geochemical indexes, such as, n-alkane, triterpenoids, sterane, and hopane, were utilized to investigate the pathways of hydrocarbon migration. Recent studies on petroleum maturity have focused on comparison of source rocks and reported that the maturity effects of source rock and reservoir oil are weak, while those effects are high in the Liuchu area. Analysis of triterpenoid and steroid hydrocarbon biomarkers elucidate the underground petroleum migration pathways to the reservoirs. Geochemical analyses of hopane and cholestanes were used. The alpha alpha alpha C29 (20 S)/(20 S + 20 R), C29 beta beta/(alpha alpha + beta beta), and C31 hopane 22R/C30 hoopane ratios, and C19/C21 tricyclic terpane ratio, C19/C21 tricyclic terpenes, C31 (22 S)/(22 S + 22 R), and C29 (20 S)/(20 S + 20 R) ratios were analyzed to determine the maturity of crude oil. Petroleum migrated along fault, sandbody, and unconformity, which suggest vertical and lateral migration occurred. Reservoir sandstone porosity and mudstone content of the thick caprock are likely to limit lateral hydrocarbon migration. Petroleum migration and accumulation primarily occurred by vertical migration and lateral migration was weak. The study offers an improved understanding of uncertain hydrocarbon migration pathways and further developed the hydrocarbon migration and accumulation models.
      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

    Regulation of oil and gas reserves reporting in Saudi Arabia: Review and recommendations

    Weijermars, RuudAl-Shehri, Dhafer
    8页
    查看更多>>摘要：The regulatory framework and guidelines for reserves reporting in Saudi Arabia are reviewed - the ongoing privatization process of the national oil company (Saudi Aramco) will benefit from the establishment of transparent asset appraisal rules. Previously, Saudi oil reserves were exclusively reported to the Organization of Petroleum Exporting Countries (OPEC) as mandated by confidential considerations and internal policies of the Saudi government. Truly independent appraisal of oil and gas reserves as commonly performed by oil and gas investment analysts becomes increasingly relevant when national oil and gas companies are seeking to privatize and must gain the trust of the international investment community. Under such scenarios the regulation of - and compliance with - the governing reserves reporting guidelines need to be conducted with the utmost transparency. Successful monetization of the corporate asset value via bond issues and initial public offerings (IPO) to potential new shareholders critically depends on independent reserves appraisals. Some of the complexities of reserves estimations for a national oil company, such as Saudi Aramco, making the transition - from a formerly wholly state-owned enterprise to a public-private-partnership company - are highlighted. Recommendations are given for improved reserves reporting governance.
      原文链接:
    • NSTL
    • Elsevier

    Performance of thermophilic strain on the reduction of viscosity of crude oil under high pressure and high temperature conditions: Experiments and modeling

    Sakthipriya, N.Doble, MukeshSangwai, Jitendra S.
    12页
    查看更多>>摘要：The matured reservoirs all over the world leads on the way to highly viscous crude oil. The heavy and waxy oil would act as an alternative to conventional reserves, only with the application of a technology to reduce the viscosity. This study aims to analyze the microbial activity on crude oil, and the synergetic effect of microbial interaction, pressure and temperature on viscosity. The reports on application of microorganisms on the viscosity reduction of crude oil are very rare at high temperature and high pressure environment. The application of Bacillus subtilis, a thermophilic bacterium for improving the flow properties of waxy crude oil is investigated at various temperatures and pressures in a high pressure cell. This study has been carried out to simulate the microbiological phenomenon occurring in the reservoir, when a bacteria is introduced for viscosity reduction. Bacillus subtilis could grow well from 0.1 to 5 MPa, and less growth was observed at 10 MPa. The maximum 52.1% of viscosity of crude oil was reduced at the pressure of 1 MPa, temperature of 50 degrees C, and at the shear rate of 1000 s-1 by microbial interaction. The implicit correlations as a function of pressure, temperature, and shear rate has been developed to predict the viscosity of crude oil during the microbial treatment. This work also proposed a new model incorporating the thermodynamic and microbial kinetics to estimate the viscosity of crude oil during the process of microbial degradation. The proposed model has provided satisfactory predictions when compared with the experimental values of degradation. All these findings demonstrate the influence and suitability of Bacillus subtilis in crude oil production and transportation.
      原文链接:
    • NSTL
    • Elsevier

    Numerical study of the mud loss in naturally fractured oil layers with two-phase flow model

    Li, LeiYang, JinSong, YuYan, De...
    9页
    查看更多>>摘要：Drilling in the naturally fractured formations always encounters severe mud loss, which endangers the drilling safety. In oil & gas layers, a larger quantity of mud loss has great adverse effects on later oil and gas production. Therefore, it makes the knowledge of mud loss very important, and after that, it is instructive to control the mud loss in the oil layer. In this paper, we first consider the mud loss process using a two-phase flow model. A discrete fracture network model is employed to describe the fluid transfer between fractures and matrix pores. And different relative permeability curves and capillary pressure functions are used in matrix pores and natural fractures. The finite element method and "upwind" scheme are employed to deduce the numerical discretized formulas. The correctness of our model is verified with the published literature. Then a sensitivity analysis is performed to study the laws of mud loss in naturally fractured oil-wet formation. Compared with single-phase flow models, the mud loss rate of two-phase flow model is lower. The two-phase flow model is used to identify the most influential factors on mud loss and predict the distribution of water saturation in oil formation during the drilling process. We find that: since the pressure increase zone is much larger than the water saturation increase zone, the size of the water invasion zone is unknown in the single-phase flow model. The most important influential factors of mud loss in the oil layer are fracture connection, drilling fluid density and matrix permeability. Once the natural fractures are connected to the wellbore, the mud loss rate is much higher than that when the natural fractures are not connected to the wellbore. The capillary pressure has little effect on the mud loss. The larger the capillary pressure, and the lower the mud loss rate. The model in this paper is instructive to learn the law of mud loss and contamination range of drilling fluids in oil layers.
      原文链接:
    • NSTL
    • Elsevier

    Effective equations for energy transport in petroleum reservoirs

    Fuentes-Ibarra, DanielCazarez-Candia, OctavioAguilar-Madera, Carlos G.
    18页
    查看更多>>摘要：Thermal enhanced oil recovery methods such as hot water flooding, steam drive, cyclic steam injection, steamassisted gravity drainage, in-situ combustion, and electrical heating involve multiphase and multicomponent thermal flow with phase change and thermal displacement which improves the oil mobility inside the porous rock. Mostly, these methods are modeled by applying mass, momentum, and energy balances at the macroscale assuming that fluids and rock grains get instantaneously the same temperature, namely thermal equilibrium. In this paper, the macroscale energy equations are theoretically derived via the volume averaging method, considering: (1) local thermal non-equilibrium with and without phase change (four-equations models), (2) pseudo-local thermal non-equilibrium (two-equations model), and (3) local thermal equilibrium (one-equation model). The starting point for the derivation of the equations is the governing energy equations at the microscale for a four-phase system (water, oil, gas, and rock). The different effective equations are obtained as well as the closure problems allowing the numerical computation of the associated effective coefficients, for instance, the effective thermal conductivity tensor contained in the one-equation model was numerically calculated and compared against available experimental data, getting reasonable accuracy. The aforementioned models will allow studying the effect of considering the local thermal non-equilibrium behavior on thermal oil recovery methods.
      原文链接:
    • NSTL
    • Elsevier

    Development of in-situ starch grafted copolymerized gels for conglomerate reservoir conformance control and oil recovery improvement

    Luo, QiangTang, KeBai, LeiLi, Kai...
    11页
    查看更多>>摘要：To improve the waterflooding efficiency in the conglomerate reservoir with severe heterogeneity in the Xinjiang Oilfield, an in-situ starch grafted copolymerized gel (ISGCG) system as a strong plugging material was developed. Through viscosity experiment, rheological measurement, gel strength test, and sand pack plugging experiment, the gelation performance of the ISGCG system were systematically evaluated in the laboratory. Experimental results showed that the ISGCG system was a typical pseudoplastic fluid. It was also a shear-thinning fluid, which is beneficial to its pumping and deep propagation in the petroleum formation. In addition, with the increase of starch concentration, both the elastic modulus (G') and viscous modulus (G '') of the gel system increased first and then decreased. When the concentration of starch reached 3 wt%, the viscoelasticity was the strongest. In addition, as the concentration of cross-linking agents increased, the gel strength also increased first and then decreased. However, the gelation time slightly changed. Moreover, with the increase of initiator concentration, the gelation time gradually reduced, but the gel strength did not change significantly. The ISGCG system had excellent injection performance in the conglomerate reservoir rocks since its viscosity was low. It also had a strong adhesion force with the reservoir sand after cross-linking, so the robust plugging strength during the secondary waterflooding process can be guaranteed. Last, the in-situ starch grafted copolymerized gel (ISGCG) has been successfully applied in a conglomerate reservoir in the Xinjiang Oilfield, China. After treatments of the ISGCG system, the daily water cut of the treated well reduced from 92.7% to a minimum of 75.8%, and the daily oil production increased from 8.1 to 18.8 t/d. It shows the ISGCG system is a promising material for conformance control and oil recovery improvement in conglomerate reservoirs.
      原文链接:
    • NSTL
    • Elsevier