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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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    Unveiling the mechanisms of in-situ combustion of post-steam driven heavy oil by electric heating method induced auto-ignition

    Kan ChangbinYu XiaocongGuan WenlongTang Junshi...
    12页
    查看更多>>摘要：Ignition design of air injection wells is the crucial factor to a successful in-situ combustion. In this paper, experimental studies were carried out on post steam flooding wells at JIN-91 of Liaohe oilfield for improving ignition success rate. The experiments were conducted by a high temperature-pressure ignition device specifically designed for in-situ combustion, and the effects of various parameters were investigated by factorial experiments. The results showed that the ignition temperature was reduced and the ignition time was shortened due to three factors: heating temperature, reservoir pressure, and clay minerals. When heating temperature exceeded 360 degrees C, experimental pressure was higher than 4.0 MPa, and 10% of montmorillonite clay was added, the crude oil samples could be ignited rapidly. According to the factorial results, the most effective method to shorten ignition time is by increasing heating temperature, the safest method to reduce crude oil spontaneous combustion temperature and to shorten ignition time is by applying clay minerals, and reservoir pressure is the key factor for safety operation during ignition operation. These results will provide experimental theoretical guidance for high efficiency ignition, process optimization, and safe implementation of crude oil reservoir, they also will deliver tech support for the high efficiency operation of in-situ combustion.
      原文链接:
    • NSTL
    • Elsevier

    A permeability model for coal based on elastic and plastic deformation conditions under the interaction of hydro-mechanical effects

    Wang, ZhonghuiLi, BoboRen, ChonghongXu, Jiang...
    15页
    查看更多>>摘要：In engineering activities involving the mining of coal resources, gas is the main factor for causing coal and gas explosions accidents, with permeability being an important parameter in estimating gas emissions. With the steady development of the mining face, stress in front of the work face has evidently changed, that has resulted in coal damage under mining disturbance. In the underground environment, coal is in a complex environment where water, gas and external loads combine with each other, leading to changes in permeability that are often extremely complex, with effective stress being the dominant factor to changes in permeability. Therefore, coal permeability change related to damage-induced effects under different water contents should be further studied. In this study, first, the influence of water, gas adsorption and effective stress on coal fracture permeability change were considered. Further, damage variables were introduced to combine mechanical damage with water weakening damage. By quantifying changes in matrix sizes with new fracture generations, the plastic deformation in fractures was estimated. Based on a cubic model, a damaged-induced permeability model under the interaction of hydro-mechanical effects was established. From this, a triaxial seepage experiment involving the whole stress-strain process, including effective stress changes of water-bearing coal, was conducted to compare with, and to verify the results against an established model. The experimental results revealed that changes in axial strain and permeability was "S" shaped during the whole stress-strain process. In addition, during the whole stress-strain and effective stress changes process, the permeability model corresponded well with the experimental results. This demonstrated that the model could not only predict permeability change under elastic deformation, but could also describe permeability changes under plastic deformation during the damage stage. The purpose of this study was to provide a new method for predicting the permeability evolution law relating to coal mining and gas extraction.
      原文链接:
    • NSTL
    • Elsevier

    The genesis of authigenic minerals and the porosity evolution of various lithologies and their implications for identifying high-quality reservoirs in the fourth member of Xujiahe Formation (Northeast-Sichuan Basin, China)

    Zhao, ChengjinJiang, YouluYang, HaixingWang, Liangjun...
    22页
    查看更多>>摘要：With petroleum exploration extending to deeper reservoirs, it becomes more and more difficult to find relatively high-quality reservoirs in heterogeneous sandstones. This research integrates fluid inclusion analysis, petrographic, mineralogical, and geochemical data to determine the origin of authigenic minerals, establish the porosity evolution model and discuss diagenetic effects on reservoir quality of the fourth member of the Upper Triassic Xujiahe Formation. The main rock types of studied sandstones are identified by thin-section, SEM and XRD analysis-feldspathic litharenites, litharenites, calcareous sandstone and chlorite-rich sandstone. Of the four types of sandstone, reservoir porosity of the chlorite-rich sandstone is generally the highest. Target sandstones have experienced complicated diagenetic histories including mechanical compaction, three stages of carbonate cementation, the dissolution of K-feldspar or rock fragments, three kinds of authigenic chlorite precipitation, and two stages of quartz precipitation. Two reaction pathways between K-feldspar and kaolinite were determined and limited dissolution was generated in the closed diagenetic system. Diagenetic sequence and porosity evolution suggest that the critical factors in reducing reservoir quality can be attributed to early intense compaction and widespread calcite cementation. The genesis of high-quality reservoirs among the various lithologies is different. In feldspathic litharenites and litharenites, the key factors for the development of relatively high-quality reservoirs is the acidic dissolution of K-feldspar and less cement being present in the rock. Because chlorite helps retain primary pores by inhibiting quartz overgrowths, almost all chlorite-rich sandstone are relatively highquality reservoirs. In general, the reservoir quality of calcareous sandstone is poor unless fractures exist that can improve permeability. Determining the porosity evolution of various lithologies is an effective method to predict relatively high-quality reservoirs, which can provide a useful reference for deep petroleum exploration in other areas.
      原文链接:
    • NSTL
    • Elsevier

    Oil production enhancement, asphaltene precipitation and permeability damage during CO2-SAG flooding of multi-layer sandstone reservoirs

    Wang, QianShen, JianGlover, Paul W. J.Lorinczi, Piroska...
    13页
    查看更多>>摘要：The process of CO2-SAG flooding involves conventional miscible CO2 flooding until breakthrough (BT), followed by a period of CO2 soaking or shut-in, and then a continuation of the miscible CO2 flooding. The SAG process provides different improvements in the oil recovery for different positions of each layer in multilayer reservoirs, and has different effects on the distribution of pore throat blocking and adsorption of asphaltene to mineral surfaces. In this paper, both miscible CO2-SAG and conventional CO2 flooding experiments have been carried out at reservoir conditions and on multi-layer systems composed of 3 long cores each with increasing porosities and permeabilities, which were connected in parallel. After CO2-SAG flooding oil recovery factors (RF) of the low, medium and high permeability cores were 7.7%, 8.3%, and 7.6% higher compared to the RFs after CO2 flooding, respectively. The respective fractional oil production (FOP) of each long core was 10.6%, 27.7%, and 61.6% after CO2-SAG flooding, with less difference between each long core than for CO2 flooding. After CO2 flooding, the permeability of the high permeability core at the injection end dropped by 24.5-25.8%, which is 5.5-14.3% higher than the value at the outlet. The permeability decrease due to CO2-SAG flooding was 0.7-9.7% higher than that due to CO2 flooding, and the distribution of permeability decline was more homogeneous. The contribution of the total permeability decrease attributable to asphaltene particle blockage due to CO2 flooding was 84.7-62.7%, 5.2-10.1% higher than that due to CO2-SAG flooding, gradually decreasing along the flow direction. Complex two-phase flow of oil and gas is more likely to cause pore throat blockage instead of causing the adsorption of asphaltene precipitation.
      原文链接:
    • NSTL
    • Elsevier

    Evaluation of the impact of CO2 geological storage on tight oil reservoir properties

    Dai, YutingLai, FengpengNi, JunLiang, Yisheng...
    11页
    查看更多>>摘要：Carbon capture, utilization, and storage (CCUS) is an emerging methodology to mitigate CO2 emissions. When injected into the subsurface, there are potential interactions between CO2, pore fluids, and the reservoir rock. To determine analyzed the effect of CO2 on the physical properties of geological reservoirs, the pore structure, and mineral composition of cores before and after CO2 static soaking. The samples were analyzed using nuclear magnetic resonance (NMR), X-ray diffraction (XRD), scanning electron microscope (SEM), and energy dispersive spectrometer (EDS). This study found that the pore size of tight sandstone core samples increases with time under the same formation water condition. At the same time, the pore changes of tight sandstone samples are different under different CO2-formation water immersion. The experimental results show that the degree of dissolution of minerals with CaCl2 formation water is negligible. Often, When CO2 injection, two phenomena usually occur. First, mineral dissolution enlarges pores. Second, the diagenetic crystallization of salt and illite divides the pores will increase the pore size. The results of the CO2-NaHCO3 static immersion show experiments that within seven days, due to salt diagenesis and mineral precipitation than mineral dissolution, the pores decrease. With the further strengthening of mineral dissolution, the pores increase during 7-12 days. In addition, in CO2-CaCl2 type formation water, only pore size decreases within the reaction time of 12 days, indicating that precipitation is more excellent than dissolution in this water environment. The comprehensive analysis shows that the effect of CO2 on pore enlargement is not unidirectional but first inhibits and then promotes pore size. After CO2 injection into the formation, it is dissolved in formation water with different chemical properties, influencing reservoir rocks. Compared with CO2- CaCl2 formation water, CO2-NaHCO3 formation water has a noticeable effect of increasing porosity, which has the potential of improving oilfield tight reservoir conditions to a certain extent.
      原文链接:
    • NSTL
    • Elsevier

    Irreversibility analysis in hydromagnetic flow of Newtonian fluid with Joule heating: Darcy-Forchheimer model

    Khan, Sohail A.Khan, M. ImranAlsallami, Shami A. M.Alhazmi, Sharifah E....
    9页
    查看更多>>摘要：Background and objective: The implication of entropy analysis is noticed in various processes like cooling system, heat exchangers, thermal systems, thermal power plants, combustion, porous media, turbine systems and nuclear reactions etc. In view of such thermal applications, the theme of this paper is to analyze the entropy optimization in chemical reactive flow of Darcy-Forchheimer viscous liquid with Lorentz force by a stretched bended sheet. Energy equation is developed through thermodynamics first law with radiation, magnetic field, heat generation and dissipation. Entropy is calculated through second law of thermodynamics. Furthermore, chemical reaction is addressed. Here heat transport phenomena for both prescribed surface temperature (PHF) and prescribed heat flux (PST) types are discussed. Methodology: The proposed systems are modeled in a curvilinear coordinate. Nonlinear dimensionless systems are obtained through implementation of suitable variables. The proposed systems are solved for convergent solution through numerical approach (ND-solve method). Results: Significant effect of entropy generation, fluid flow, concentration, thermal filed and Bejan number against influential variables are studied. Computational analysis of skin friction and thermal transport rate via flow variables are discussed. Here heat transport rate for both (PHF) and (PST) cases are studied. A reverse scenario is seen for fluid flow and thermal field through Hartman number. A decrement in fluid flow is noticed for porosity variable. Conclusions: A similar impact holds for entropy rate and thermal field through radiation effect. An intensification in curvature variable improves both fluid flow and concentration. A reverse trend for Bejan number and thermal field is seen through Brinkman number. Reduction occurs in concentration with higher Schmidt number. An amplification in drag force is observed for Hartman number, while reverse effect holds for curvature variable. An intensification in porosity variable rises both entropy and Bejan numbers. Higher approximation of curvature parameter reduces thermal transport rate for prescribed surface temperature (PHF) while reverse trend holds for prescribed heat flux (PST).
      原文链接:
    • NSTL
    • Elsevier

    Modeling subsea gas-liquid separation using proxy for phase separation for pre-salt reservoirs with high GOR

    Vaz, Rodrigo Goncalvesvon Hohendorff Filho, Joao CarlosBotechia, Vinicius EduardoSchiozer, Denis Jose...
    6页
    查看更多>>摘要：Brazilian pre-salt oil fields include ultra-deep water reservoirs with high CO2 content and high gas/oil ratio (GOR). For these cases, large volumes of CO2-rich gas reach the topside facilities that present limited gas processing capacity. In this context, the production of the oil field is restricted to the maximum gas production capacity of these facilities. The use of a subsea gas-liquid separation (SGLS) and reinjection system may be a solution to boost oil production, as this strategy allows reinjecting part of produced gas directly from the seabed. In this study, we developed a methodology for modeling the subsea separation and reinjection process, which is integrated with a compositional reservoir simulator. A proxy based on an equation of state (EOS) was used for volumetric phase separation in the subsea separator. This approach eliminates the necessity of flash calculation at the SGLS conditions. The methodology makes it possible to assess the potential impact of implementing this technology from a reservoir management perspective. The modeling methodology is applied to a benchmark case (synthetic simulation model representative of a pre-salt reservoir) and evaluated the impact of the SGLS over total production. The results show that the SGLS technology can successfully boost oil production in the context of platform gas production restriction. As soon as the SGLS was implemented, an extended oil production plateau was achieved due to increased gas production capacity. We observed a significant GOR increment in produced fluids during the simulation as a result of gas recycling strategy. This increasing GOR caused the field production to be restricted by maximum gas production constraint most of the time, despite the SGLS implementation. A higher GOR also affects the SGLS performance, increasing the proportion of gas that becomes available for separation at subsea separator conditions. An economic analysis is presented, showing that the SGLS has the potential to increase the financial return of the project. The introduced methodology will enable the inclusion of the subsea separation process in future analyses, paving the way for feasibility assessments and optimization processes for cases in which the SGLS may be an alternative.
      原文链接:
    • NSTL
    • Elsevier

    Experimental investigation of the flow conductivity characteristics in shale's single fracture under the PHF stimulation

    Cao, HanZhu, HaolongGao, QiangChen, Yu...
    10页
    查看更多>>摘要：The pulsating hydraulic fracturing (PHF) technology can be employed to improve the shale's permeability more effectively comparing to the conventional fracturing method. To understand the mechanism of flow conductivity under the PHF, we investigated the shale's conductivity capacity using pulsating fracturing test device. The experiments are conducted on the different closure pressures to monitor the shale's flow conductivity in the artificial fracture under the pulsating fracturing stimulation. The results reveal that the fracture surface coin-cidence degree (FSCD) and the flow rate are affected by the closure pressure, as well as there is a good linear correlation between variations of FSCD and flow rate. As the closure pressure increases from 4 MPa to 6 MPa, the flow rate declines by 58.82%. Moreover, a prediction model for the conductivity capacity in shale's single fracture under pulsating hydraulic fracturing is proposed. It can well predict the fracture conductivity capacity when the closure pressure range in 4-10 MPa, which is helpful to evaluate the economic benefits of fracturing.
      原文链接:
    • NSTL
    • Elsevier

    Microemulsion interface model for chemical enhanced oil recovery design

    Hon, Vai YeeSaaid, Ismail MohdChai, Ivy Ching HsiaDeguillard, Estelle...
    9页
    查看更多>>摘要：The surfactant phase behavior laboratory test for chemical enhanced oil recovery (EOR) formulation design is time consuming. However, it is possible to use computational chemistry simulation to minimize the duration. The only known non-empirical approach to predict surfactant phase behavior is by surface tension analysis, but the optimum phase behavior boundary is unclear and its applicability in actual complex crude oil is unproven. This research overcomes these issues by developing a microemulsion interface model using digital oil model with accurate representation of atomistic components of actual crude oil as inputs to the simulation. The micro emulsion interface model is developed based on physical chemistry of surface tension and torque concepts coupled with solution of interface bending rigidity in relation to surfactant solubilization and interface energy. The model is implemented in coarse-grained molecular dynamics simulation technique. The microemulsion interface model is verified with surfactant phase behavior laboratory data using actual crude oil. Good agreement for 12 out of 14 chemical EOR formulations between simulations and phase behavior laboratory results is achieved. This indicates that the main characteristics and physics of the formation of optimal microemulsion were captured correctly in the microemulsion interface model. The duration for surfactant phase behavior determination can be reduced from 14 days in laboratory down to 1.5 day by using the microemulsion interface model, resulting in 90%-time reduction. This faster and more informed formulation development process can minimize time and costly resources as chemical EOR formulations proceed into field implementation.
      原文链接:
    • NSTL
    • Elsevier

    Pore-scale investigation of immiscible fluid displacement process in randomly distributed bead-based porous micromodels using Micro-PIV

    Sharma, Vikas KumarBhowmik, RupakTiwari, PankajSingh, Anugrah...
    16页
    查看更多>>摘要：This study reports pore-scale immiscible displacement processes in a bead-based porous micromodel using fluorescence microscopy and micro-particle image velocimetry (mu-PIV) technique. The porous micromodels with heterogeneous and homogeneous geometry are fabricated to investigate the effect of displacing phase viscosity and flow rate on the pore-scale displacement mechanism. The phenomena of shear-induced circulations and viscous instability are observed during the displacement of the trapped non-wetting phase through the porous domain. Breakage and coalescence of the droplets of the non-wetting phase were also observed during the displacement process. The velocity vector maps show that there is frequent flow reversal of ganglia, leading to an unsteady flow behaviour during the displacement process. The effect of flow rate and viscosity on the trapped non-wetting phase is investigated, and the results obtained indicate that an increase in the flow rate reduces the trapped non-wetting fluid saturation in the porous medium by disintegrating large ganglia into small droplets. Increasing either the flow rate or viscosity increases the shear stress at the interface of the trapped ganglion and displacing phase, leading to shear-induced circulations, and the strength of the vortex is found to increase. These circulations inhibit further displacement of the trapped fluids. At higher flow rate with more viscous displacing phase, the trapped non-wetting phase ganglion disintegrate into smaller droplets. It is observed that a heterogeneous micromodel causes significant trapping and lesser mobilization of the non-wetting phase compared to a homogeneous system. The porous medium with low porosity and a higher degree of heterogeneity results in more trapping and less recovery of the non-wetting phase.
      原文链接:
    • NSTL
    • Elsevier