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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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    Well safety and integrity evaluation of offshore wells: A review of past, present, and future

    Jaculli, Marcelo AnunciacaoChoueri Jr, Nelsonda Mata, Cristian RobertoAparecida Silva Leite, Amanda Gabriela...
    17页
    查看更多>>摘要：Accidents play an important role in the oil and gas industry because, among other consequences, they redefine definitions of safety. One of them is the Macondo accident, which happened in 2010 and changed the industry dramatically in terms of well safety and integrity. This work provides a literature review of well safety and integrity, divided into three eras: "the past" (pre-Macondo), "the present" (post-Macondo), and "the future" (digitalization and carbon neutrality). Our goal is to highlight the changes that the industry has undergone due to this event but also due to recent trends such as digitalization and carbon neutrality. The introduction contains a glossary of relevant definitions that are widely used in these subjects. The past reviews well integrity systems that companies had before the Macondo accident, illustrating their deficiencies compared to current systems. We also present available regulations, standards, and guidelines and what changed in them due to the accident. The present reviews current well integrity management systems (WIMS), their architectures, and studies of selected well barrier elements (fluid, BOP, wellhead, rock, and primary cementing). Finally, the future reviews ongoing trends such as the use of digitalization (through digital twins) to monitor and assess well integrity and the deployment of CCUS (carbon capture, utilization, and storage) wells to achieve carbon neutrality.
      原文链接:
    • NSTL
    • Elsevier

    Modeling tracer flowback behaviour for a multifractured horizontal well in a tight oil reservoir using the embedded discrete fracture model

    Liu, JinjuJiang, LiwuLiu, TongjingYang, Daoyong...
    16页
    查看更多>>摘要：Tracer flowback testing has been proven as an efficient method to characterize hydraulic fractures and predict the performance of a hydraulically fractured well in a tight oil reservoir; however, few efforts have been made to characterize such fracture networks by quantifying tracer flowback behaviour due to the associated technical challenges. In this work, an efficient and effective numerical model based on the embedded discrete fracture model (EDFM) was developed, validated, and applied to characterize complex fracture networks and evaluate tracer flowback behaviour for a multistage fractured horizontal well. More specifically, such a model is applied to deal with complex fractures by dividing the fractures into segments using matrix grid boundaries and creating non-neighbouring connections (NNCs) using structured grids, while the complex fracture networks can be characterized by matching tracer flowback profiles with consideration of tracer dispersion and adsorption effects. Then, tracer flowback profiles for a fractured horizontal well with different fracture network patterns, including bi-wing fracture network (BWFN), opening-fissure fracture network (OFFN), fractal-like fracture network (FLFN), and mutually orthogonal fracture network (MOFN) are obtained. It should be noted that tracer flowback concentration (TFC) varies greatly with different fracture network patterns. Sensitivity analyses have been performed to examine the influence of different parameters (i.e., fracture width, fracture porosity, fracture conductivity, tracer adsorption, and tracer adsorption capacity) on the tracer flowback response for a fractured horizontal well with the BWFN and OFFN. It is found that the TFC increases as the fracture conductivity increases, while it decreases as the adsorption capacity increases. The higher the tracer dispersion coefficient is, the lower the tracer flowback peak concentration will be. Also, this model was validated and then extended to a field case, indicating the accuracy and efficiency of the newly proposed method to characterize the fracture networks compared with the microseismic events.
      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

    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

    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

    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

    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

    Fracture development and inter-well interference for shale gas production from the Wufeng-Longmaxi Formation in a gentle syncline area of Weirong shale gas field, southern Sichuan, China

    Ge, XunGuo, TonglouMa, YongshengWang, Guoli...
    14页
    查看更多>>摘要：The Weirong shale gas field, located within a low-steep structural belt in southern Sichuan Basin, China, is characterized by gentle structural deformation. Production results have shown that inter-well interference, also known as fracture channeling, affects the productivity of shale gas wells by facilitating fluid flow between wells along pre-existing natural fractures. In this study, we used core observational data, scanning electron microscopy, and image logging analysis to determine the type, intensity, occurrence, and genetic mechanism of the natural fractures in the Upper Ordovician Wufeng-Silurian Longmaxi Formation. Attributes such as seismic coherence, AFE (fault-enhanced attribute), dip, and curvature were utilized to predict the macro and meso fault fractures in the study area. We modeled the micro fault-fractures using the seismic and tracking algorithm to characterize the faults at multiple scales in the Weirong shale gas field, and then completed a comprehensive evaluation of the overall fracture development patterns with respect to the fracture channeling of neighboring shale gas wells. Results indicate that both horizontal and vertical structural fractures have been developed in the shale reservoir of the Wufeng-Longmaxi Formation in the Weirong shale gas field, although the horizontal fractures heavily outnumber the inclined ones. While a few high-conductivity macro and meso fractures display a NE-SW strike, abundant micro-faults have NE-SW and NWW-SEE strikes. Due to the pre-existing basement faults, stress fields and micro-amplitude structure, the NWW-SEE-trending micro fault-fractures are more active than those oriented in the NE-SW direction. Based on field observations, we conclude that regions with well-developed natural fault-fracture networks are more likely to have experienced fracture channeling between or within the platforms of well groups; and the NWW-SEE-trending micro fault-fractures generate more inter-well interference than the NE-SW-trending ones. Predicting the distribution and understanding the origin of the micro fault fractures make it possible to prevent or mitigate the effects of fracture channeling during the drilling and artificial stimulation of shale gas wells.
      原文链接:
    • NSTL
    • Elsevier

    Petroleum reservoir parameters estimation using non-isothermal transient model and optimization methods

    Goncalves, Willer P.Quinones, Danmer M.Barreto Jr, Abelardo B.Carvalho, Marcio S....
    18页
    查看更多>>摘要：Traditionally, oil well tests aim to characterize the reservoir permeability field from pressure transient analysis (PTA) of drawdown and build up based on isothermal flow models in porous media. With the advancement of well test instrumentation, more accurate temperature records became available and have encouraged analyses based on non-isothermal models that made possible the temperature transient analysis (TTA). In addition to the characterization of reservoir parameters, such as permeability and porosity by TTA, taking non-isothermal effect into account on PTA represents better physical phenomena, especially in high transmissibility reservoirs and in cases where the pressure sensor is placed away from the sandface. This work consists in the development and numerical implementation of a non-isothermal model of well test considering a unidimensional radial reservoir coupled to a production well and in the use of this simulator, associated with multivariable optimization methods, to solve the inverse problem of reservoir parameters characterization. Nelder-Mead Simplex, NewtonRaphson and BGFS methods were used to evaluate reservoir parameters for one of the reservoir configurations analyzed and the first method presented better computational efficiency. It was then used to solve the inverse problem of radial composite reservoirs.
      原文链接:
    • NSTL
    • Elsevier