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Rapid screening and optimization of CO2 enhanced oil recovery operations in unconventional reservoirs: A case study 非常规油藏CO2提高采收率的快速筛选与优化：一个案例研究

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.03.001

Shuqin Wen , Bing Wei , Junyu You , Yujiao He , Qihang Ye , Jun Lu

CO₂ injection not only effectively enhances oil recovery (EOR) but also facilitates CO₂ utilization and storage. Rapid screening and optimization of CO₂-EOR operations is urgently needed for unconventional reservoirs. However, it remains challenging due to a limited understanding of fluid flow in multiscale porous media and the problem complexity invoked by numerous factors. This work developed a new interpretable machine learning (ML) framework to specifically address this issue. Three different methods, namely random forest (RF), support vector regression (SVR), and artificial neural network (ANN), were used to establish proxy models using the data from a specific unconventional reservoir, and the RF model demonstrated a preferable performance. To enhance the interpretability of the established models, the multiway feature importance analysis and Shapley Additive Explanations (SHAP) were proposed to quantify the contribution of individual features to the model output. Based on the results of model interpretability, the genetic algorithm (GA) was coupled with RF (RF-GA model) to optimize the CO₂-EOR process. The proposed framework was validated by comparing the GA-RF predictions with simulation results under different reservoir conditions, which yielded a minimum relative error of 0.34% and an average relative error of 5.3%. The developed interpretable ML method was capable of rapidly screening suitable CO₂-EOR strategies based on reservoir conditions and provided a practical example for field applications.

注入二氧化碳不仅能有效提高采收率，还能促进二氧化碳的利用和储存。非常规油藏迫切需要快速筛选和优化CO2-EOR作业。然而，由于对多尺度多孔介质中流体流动的理解有限，以及许多因素引起的问题复杂性，这仍然具有挑战性。这项工作开发了一个新的可解释机器学习（ML）框架来专门解决这个问题。采用随机森林（RF）、支持向量回归（SVR）和人工神经网络（ANN）三种不同的方法，利用特定非常规油藏的数据建立代理模型，RF模型表现出较好的性能。为了提高已建立模型的可解释性，提出了多向特征重要性分析和Shapley加性解释（SHAP）来量化单个特征对模型输出的贡献。基于模型可解释性的结果，将遗传算法（GA）与RF （RF-GA模型）相结合，对CO2-EOR过程进行优化。通过将GA-RF预测结果与不同储层条件下的模拟结果进行对比，验证了该框架的有效性，最小相对误差为0.34%，平均相对误差为5.3%。开发的可解释ML方法能够根据油藏条件快速筛选合适的CO2-EOR策略，并为现场应用提供了实际示例。

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引用次数: 0

Micro- and macroscopic experiments on self-adaptive mobility control and displacement efficiency of carbon-based composite nanofluid for enhanced oil recovery 碳基复合纳米流体自适应流动性控制及驱替效率的宏观微观实验研究

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.01.001

Rui Liu , Jie Deng , Wanfen Pu , Yue Li , Yuanyuan Lu , Binyang Zou , M.A. Varfolomeev , Chengdong Yuan

Reservoir heterogeneity, unfavorable water–oil mobility ratio, and high oil-water interface energy are primary constraints impeding macroscopic sweep and microscopic oil displacement efficiencies of water flooding reservoirs. Nanofluid's unique interface and small-scale effects offer significant potential in solving the low-universal problem of water flooding reservoir recovery. In the study, systematic micro- and macroscopic experiments, including microscopic visualization, core flooding, and nuclear magnetic resonance online flooding experiments, to reveal unique self-adaptive mobility control and superior displacement efficiency of amphiphilic graphene oxide (GOC)-based composite nanofluid. The results indicate that GOC nanosheets exert negative curvature at the oil-water interface, forming water-in-oil Pickering emulsion thermodynamically. These Pickering emulsions exhibit remarkable properties, with up to 90% internal phase volume and higher viscosity than oil across a broad water saturation, signifying GOC's self-adaptive mobility control in porous media. Furthermore, the Jiamin effect and in-situ thickening characteristics from the emulsion's micro-size compensate porous media heterogeneity, significantly improving the GOC nanofluid's macroscopic sweep efficiency. Moreover, a slight surfactant addition to the nanofluid further reduces oil-water interfacial tension to 10⁻² mN/m and regulates the rock surface's hydrophilic wettability, notably improving microscopic oil displacement efficiency. Therefore, the remaining oil and residual oil after brine flooding have been effectively utilized and efficiently displaced. The composite nanofluid with 0.3–0.7 pore volumes enhances oil recovery by 15.8%–37.7% after ultimate brine flooding. Moreover, carbon-based nanomaterials' synthesis is eco-friendly, and both carbon-based composite nanofluid preparation and the injection process are simple. These advantages show nanotechnology's excellent industrial application potential in improving oil recovery efficiency.

储层非均质性、不利的水油流度比和油水界面能过高是制约水驱油藏宏观波及和微观驱油效率的主要因素。纳米流体独特的界面和小尺度效应为解决水驱油藏低普遍性问题提供了巨大的潜力。本研究通过系统的微观和宏观实验，包括微观可视化、岩心驱油、核磁共振在线驱油实验，揭示了两亲性氧化石墨烯（GOC）基复合纳米流体独特的自适应迁移率控制和优越的驱油效率。结果表明：GOC纳米片在油水界面处产生负曲率，形成油包水Pickering乳状液；这些Pickering乳剂表现出非凡的性能，在很宽的含水饱和度下，其内相体积高达90%，粘度高于油，这表明GOC在多孔介质中具有自适应迁移率控制能力。此外，乳状液微观尺寸的嘉民效应和原位增稠特性补偿了多孔介质的非均质性，显著提高了GOC纳米流体的宏观波及效率。此外，在纳米流体中添加少量表面活性剂可进一步降低油水界面张力至10−2 mN/m，调节岩石表面的亲水润湿性，显著提高微观驱油效率。因此，盐水驱后的剩余油和剩余油得到了有效利用和高效驱替。孔隙体积为0.3 ~ 0.7的复合纳米流体在最终盐水驱后可提高采收率15.8% ~ 37.7%。此外，碳基纳米材料的合成是生态友好的，碳基复合纳米流体的制备和注射过程都很简单。这些优点表明纳米技术在提高采收率方面具有良好的工业应用潜力。

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引用次数: 0

Development directions of formation damage evaluation and fracturing fluids in tight and shale oil reservoirs 致密油和页岩油储层损伤评价及压裂液研究的发展方向

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.02.004

Lijun You , Yunsong Xie , Yang Chen , Yili Kang , Chen Huang , Huaijian Zhai

Tight and shale oil reservoirs are characterized by small pore throats, low porosity, and low permeability, which must be stimulated to increase production. Fluid flow experiences a multi-scale transport process, starting from the matrix pore throats, extending to the natural fractures, and reaching the hydraulic fractures. Initially, tight and shale oil wells exhibit high production rates after hydraulic fracturing. However, this rapidly decreases due to insufficient energy in the reservoir, as well as formation damage to the reservoir, which impedes the multi-scale transport process. Consequently, effective systems for low-damage slickwater fracturing fluids and clean fracturing fluids to ensure the scale and effective development of tight and shale oil reservoirs after volume stimulation have been widely used. The pressure decay method and high back pressure displacement method have provided the valuable foundations for selecting fracturing fluids for tight and shale oil reservoirs. Nonetheless, challenges such as slow fluid transfer unpropped fracture closure, and water-phase trapping damage in tight and shale oil reservoirs need to be addressed urgently. Therefore, integrating fracture preservation, energy enhancement, and damage removal concepts will be essential for successful reservoir stimulation in tight and shale oil reservoirs. Additionally, exploring matching formation damage evaluation and fracturing fluid optimization technologies is crucial to achieving the efficient development of tight and shale oil reservoirs. These will all improve fracture stimulation effects and reservoir recovery, ultimately maximizing the reservoir potential.

致密油和页岩油储层具有孔喉小、孔隙度低、渗透率低的特点，必须对其进行增产处理。流体的流动经历了一个多尺度的输运过程，从基质孔喉开始，延伸到天然裂缝，最后到达水力裂缝。最初，致密油和页岩油在水力压裂后表现出较高的产量。然而，由于储层能量不足，以及地层对储层的破坏，阻碍了多尺度运移过程，这一数值会迅速下降。因此，高效的低损伤滑溜水压裂液和清洁压裂液体系被广泛应用，以确保致密油和页岩油储层在体积改造后的规模和有效开发。压力衰减法和高背压驱替法为致密油和页岩油储层压裂液的选择提供了有价值的依据。尽管如此，诸如流体输送缓慢、无支撑的裂缝闭合、致密油和页岩油储层中的水相圈闭损害等挑战仍亟待解决。因此，整合裂缝保护、增强能量和去除损害的概念对于致密油和页岩油储层的成功增产至关重要。此外，探索相匹配的地层损害评价和压裂液优化技术对于实现致密油和页岩油储层的高效开发至关重要。这些都将提高裂缝增产效果和油藏采收率，最终使油藏潜力最大化。

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引用次数: 0

Predicting water-based drilling fluid filtrate volume in close to real time from routine fluid property measurements 通过常规流体特性测量，接近实时地预测水基钻井液滤液体积

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.03.002

Shadfar Davoodi , Mohammed Ba Geri , David A. Wood , Mohammed Al-Shargabi , Mohammad Mehrad , Alireza Soleimanian

Drilling operations depend on precisely controlling drilling fluid filtration volume (FV), which affects formation integrity, costs, and borehole stability. Maintaining optimal FV is essential to prevent well control issues, yet forecasting it is challenging due to process complexity and measurement limitations. This study adapts machine and deep learning (ML/DL) models to predict FV in almost real-time based on more easily measured fluid properties. Radial-basis-function neural network (RBFNN), generalized regression neural network (GRNN), multilayer perceptron (MLP), convolutional neural network (CNN), and Gaussian process regression (GPR) ML models are applied to 1186 records of density, viscosity, and solids content in water-based drilling fluids deployed in fourteen wellbores. CNN outperformed other models with the lowest root mean square error (RMSE) of 0.5381 mL and demonstrated resilience to overfitting and noisy data, unlike RBFNN and GRNN. The proposed method provides reliable near-real-time FV predictions, which could be beneficial in optimizing drilling operations by helping prevent potential drilling-fluid-related issues. Fast and accurate FV forecasting from routine fluid properties represents a crucial advancement for drilling operations, highlighting the need for future dataset expansion to encompass a wider range of conditions and fluid types.

钻井作业依赖于精确控制钻井液滤过量（FV），而FV会影响地层完整性、成本和井眼稳定性。保持最佳FV对于防止井控问题至关重要，但由于工艺复杂性和测量限制，预测FV具有挑战性。该研究采用机器和深度学习（ML/DL）模型，基于更容易测量的流体特性，几乎实时地预测FV。径向基函数神经网络（RBFNN）、广义回归神经网络（GRNN）、多层感知器（MLP）、卷积神经网络（CNN）和高斯过程回归（GPR） ML模型应用于14口井中部署的水基钻井液的密度、粘度和固体含量的1186条记录。与RBFNN和GRNN不同，CNN以最低的均方根误差（RMSE） 0.5381 mL优于其他模型，并表现出对过拟合和噪声数据的弹性。该方法提供了可靠的近实时FV预测，有助于通过防止潜在的钻井液相关问题来优化钻井作业。从常规流体性质中快速准确地预测FV是钻井作业的重要进步，强调了未来数据集扩展的需求，以涵盖更广泛的条件和流体类型。

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引用次数: 0

Study on rapid construction of microemulsion system based on EACN of crude oil measured by the direct method 基于直接法测得原油EACN的微乳体系快速构建研究

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.02.001

Yibo Li , Min Yang , Tianshuang He , Jutao Chen

The purpose of this study is to delineate the applicability of the direct method for determining the equivalent alkane carbon number (EACN), a crucial parameter in the hydrophilic-lipophilic deviation (HLD) theory, and to validate the efficacy of microemulsion systems formulated using this theory. The workload associated with constructing microemulsion systems can be substantially minimized through the application of the HLD theory, yet the accuracy and efficiency of this approach necessitate verification. Notably, the scope of application for the direct method in measuring EACN remains ambiguous. To address this, three different crude oil samples were analyzed, with their EACN values measured using the direct method. Subsequently, based on these measurements, microemulsion systems were screened and constructed according to the HLD theory. Adaptability experiments, interfacial tension assessments, and core displacement experiments were conducted to evaluate the system’s performance and its capacity to enhance oil recovery. The results indicate that the direct method has limitations in measuring the EACN of crude oil, particularly for heavy oils with complex compositions, but it is suitable for light oils with simpler compositions. Furthermore, the core displacement experiment revealed that for light oil from Xinghua Oilfield, the formulated system achieved a notable increase in recovery by 15.44%, demonstrating a significant enhancement in oil recovery.

本研究的目的是描述确定等效烷烃碳数（EACN）的直接方法的适用性，EACN是亲水-亲脂偏差（HLD）理论中的一个关键参数，并验证使用该理论制定的微乳液体系的有效性。通过应用HLD理论，可以大大减少与构建微乳液系统相关的工作量，但该方法的准确性和效率需要验证。值得注意的是，测量EACN的直接方法的应用范围仍然不明确。为了解决这个问题，研究人员分析了三种不同的原油样品，并使用直接法测量了它们的EACN值。随后，基于这些测量结果，根据HLD理论筛选和构建微乳液体系。通过适应性实验、界面张力评估和岩心位移实验来评估该体系的性能及其提高采收率的能力。结果表明，直接法测定原油的EACN有一定的局限性，特别是对成分复杂的重油，但适用于成分简单的轻质油。岩心驱替实验表明，对于兴化油田的轻质油，该配方体系的采收率提高了15.44%，明显提高了采收率。

{"title":"Study on rapid construction of microemulsion system based on EACN of crude oil measured by the direct method","authors":"Yibo Li , Min Yang , Tianshuang He , Jutao Chen","doi":"10.1016/j.petlm.2025.02.001","DOIUrl":"10.1016/j.petlm.2025.02.001","url":null,"abstract":"<div><div>The purpose of this study is to delineate the applicability of the direct method for determining the equivalent alkane carbon number (EACN), a crucial parameter in the hydrophilic-lipophilic deviation (HLD) theory, and to validate the efficacy of microemulsion systems formulated using this theory. The workload associated with constructing microemulsion systems can be substantially minimized through the application of the HLD theory, yet the accuracy and efficiency of this approach necessitate verification. Notably, the scope of application for the direct method in measuring EACN remains ambiguous. To address this, three different crude oil samples were analyzed, with their EACN values measured using the direct method. Subsequently, based on these measurements, microemulsion systems were screened and constructed according to the HLD theory. Adaptability experiments, interfacial tension assessments, and core displacement experiments were conducted to evaluate the system’s performance and its capacity to enhance oil recovery. The results indicate that the direct method has limitations in measuring the EACN of crude oil, particularly for heavy oils with complex compositions, but it is suitable for light oils with simpler compositions. Furthermore, the core displacement experiment revealed that for light oil from Xinghua Oilfield, the formulated system achieved a notable increase in recovery by 15.44%, demonstrating a significant enhancement in oil recovery.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 201-210"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883063","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 0

An environmentally friendly and low-cost alginate-based gel for water management in petroleum reservoirs: Characterization and efficacy investigation 一种环境友好、低成本的海藻酸盐基油藏水管理凝胶：表征和效果研究

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.03.003

Maede Ayari , Shahriar Osfouri , Reza Azin , Amir Rostami

Water production in petroleum reservoirs poses considerable challenges, such as lower production efficiency, higher operational costs, and severe environmental risks. This study investigates the effectiveness of a novel, sustainable, and economical alginate-based gel system derived from Persian Gulf brown algae in decreasing reservoir rock water permeability. The ultrasonic-assisted method retrieved the most alginate, yielding 56% at a pH, alginate-to-water ratio, sonication time, and ultrasound power of 11, 10 g/L, 45 min, and 75 W, respectively. The FTIR spectrum showed that the alginate structure had O–H, C–H, CC, and C–O functional groups. Also, TGA results indicate that the extracted alginate is thermally stable. The effects of polymer concentration, cross-linker content, pH, temperature, and solvent salinity on the properties of the natural gel system were investigated. While the gel strength rose with increasing polymer and cross-linker concentrations, the gelation time decreased. Also, increasing the acidity of the system resulted in higher gel viscosity, attributed to stronger molecular binding. Seawater-based gels exhibited greater strength than distilled water gels due to divalent ions (Mg²⁺, Ca²⁺) in seawater. The sand-pack experiments demonstrated the ability of the polymer-gel system, which included 3 wt% of the alginate polymer and 1 wt% of CaCl₂, to reduce permeability by 44.7%. Furthermore, the coreflood experiments conducted on a carbonate reservoir rock demonstrated the feasibility of in-situ gel formation and a 22.7% reduction in permeability by injecting a 0.5 wt% alginate solution. The results showed that the sustained gel functioned as a blocking agent by significantly diminishing the water permeability.

油藏采水面临着诸多挑战，如生产效率低、作业成本高、环境风险严重等。本研究探讨了一种新型的、可持续的、经济的海藻酸盐凝胶体系在降低储层岩石渗透率方面的有效性。超声辅助法在pH、海藻酸与水比、超声时间和超声功率分别为11、10 g/L、45 min和75 W时，提取海藻酸盐最多，回收率为56%。FTIR光谱表明，藻酸盐结构具有O-H、C-H、CC和C-O官能团。TGA结果表明，提取的海藻酸盐具有热稳定性。考察了聚合物浓度、交联剂含量、pH、温度和溶剂盐度对天然凝胶体系性能的影响。随着聚合物和交联剂浓度的增加，凝胶强度增加，凝胶时间缩短。此外，增加体系的酸度导致更高的凝胶粘度，这归因于更强的分子结合。由于海水中的二价离子（Mg2+, Ca2+）的存在，海水基凝胶比蒸馏水凝胶表现出更高的强度。填砂实验表明，聚合物-凝胶体系（其中含有3wt %的海藻酸盐聚合物和1wt %的CaCl2）能够降低44.7%的渗透率。此外，在碳酸盐岩储层上进行的岩心驱油实验证明了原位凝胶形成的可行性，通过注入0.5 wt%的海藻酸盐溶液，渗透率降低了22.7%。结果表明，持续凝胶的阻水作用显著降低了水渗透性。

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引用次数: 0

Optimizing heavy crude oil conversion: Catalytic thermolysis with TiO2@α-Fe2O3 nanocomposite and surfactant dynamics 重质原油转化优化：TiO2@α-Fe2O3纳米复合材料催化热解及表面活性剂动力学

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.02.003

Asmaa S. Morshedy , Tahany Mahmoud

Currently, as the production of light crude oil is reaching its peak, the focus of the petroleum industry is shifting towards significant amount of heavy oil to meet the increasing need for energy and fuels. Heavy oil is typically categorized by its high density, great viscosity with small API gravity, high hetero-atom content and limited low boiling point fuel fraction yield compared to light oil. One approach for enhancing the flow characteristics of heavy oil before the recovery process is introducing catalysts into the reservoir. This scientific research focuses on the preparation and characterization of (10%, 20%, 30%) TiO₂@α-Fe₂O₃ nanocomposite catalysts for potential catalytic applications. The study outlines the synthesis method used to create different ratios of as-prepared nanocomposites. It provides detailed characterization through various analytical techniques. The results highlight the successful formation of X% TiO₂@α-Fe₂O₃ nanocomposites with well-defined structures and optimized properties for catalytic reactions. The study investigates the impact of this nanocomposite on the rheological characterizations of heavy crude oil, focusing on the capability of decreasing viscosity and advance flow characteristics. The experimental results demonstrate notable improvements in viscosity reduction and enhancing heavy crude oil production processes as the best results obtained by (0.5 wt%) 20% TiO₂@α-Fe₂O₃ (62.6% after 2 h at 200 °C). The asphaltene and resin ratio decreased by 54.5% and 68.1% respectively. The saturated and aromatic content shows 67.56% and 15.91% respectively at the same conditions. The presence of different surfactants (non-ionic and anionic) gives a synergetic effect which reveals active participation of contact angle changing and Interfacial tension (IFT) reduction. This research contributes to the advancement of methods for upgrading heavy crude oil, offering a promising avenue for increasing efficiency and productivity in the oil industry.

目前，随着轻质原油的产量达到峰值，石油工业的重点正在转向大量的重油，以满足日益增长的能源和燃料需求。与轻质油相比，重油通常具有密度高、粘度大、API比重小、杂原子含量高和低沸点燃料馏分收率有限等特点。在采油前提高稠油流动特性的一种方法是在储层中引入催化剂。本科学研究的重点是（10%,20%,30%）TiO2@α-Fe2O3纳米复合催化剂的制备和表征。该研究概述了用于制造不同比例的纳米复合材料的合成方法。它通过各种分析技术提供了详细的表征。结果表明，X% TiO2@α-Fe2O3纳米复合材料的成功形成具有明确的结构和优化的催化反应性能。该研究考察了这种纳米复合材料对重质原油流变特性的影响，重点研究了其降低粘度和改善流动特性的能力。实验结果表明，（0.5 wt%） 20% TiO2@α-Fe2O3（在200℃下作用2 h后达到62.6%）对降低稠油粘度和提高稠油收率有显著的改善作用。沥青质比和树脂比分别下降54.5%和68.1%。在相同条件下，饱和和芳香含量分别为67.56%和15.91%。不同表面活性剂（非离子和阴离子）的存在产生了协同效应，显示了接触角改变和界面张力（IFT）降低的积极参与。该研究有助于提高重质原油的改造方法，为提高石油工业的效率和生产力提供了一条有前途的途径。

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引用次数: 0

Exploring hydrocarbon potential with 3D modeling techniques: Lower Cretaceous formations in Abu Sennan field, north Western Desert 利用3D建模技术勘探油气潜力：西北沙漠Abu Sennan油田下白垩统地层

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.03.004

Taher Mostafa , Mohamed Reda , Mohamed Mosaad , Dmitriy Martyushev , Mansour H. Al-Hashim , Mohamed Fathy

The northern portion of the Egyptian Western Desert is a very promising oil-producing province. The Abu Roash and Bahariya formations in Abu Sennan Field have a diverse lithological composition, leading to variances in reservoir continuity both horizontally and vertically. The reservoir heterogeneity problem is addressed by utilizing datasets derived from five wells and 3D seismic data that covers the full region of Abu Sennan. The lithology and reservoir levels were determined using geophysical well data. The investigated formations consist of sandstone, carbonate, and shale. The “E” and “G” members of the Abu Roash Formation, in addition to the Bahariya Formation, have the highest potential for containing hydrocarbons. Abu Roash E has a range of net pay from 17–47 m, shale volume ranging from 17% to 36%, effective porosity ranging between 20% and 26%, and oil saturation ranging between 49% and 77%. The Abu Roash “G” has a net pay range of 7–34 m, a shale content ranging from 5% to 42%, an effective porosity between 10% and 24%, and a hydrocarbon saturation ranging from 46% to 60%. The Bahariya Formation has a vertical thickness of 12–62 m, with a percentage of shale ranging from 16% to 44%. The formation also exhibits an effective porosity ranging from 15% to 26% and an oil saturation ranging between 46% and 77%. Analyzed 3D seismic data were utilized to create depth-structure maps. Seismic data interpretation and petrophysical analysis enabled the creation of 3D models for the structures and reservoirs in the Abu Sennan region. The static models served as the main inputs for calculating the volumetrics and generating two additional interesting opportunities in the researched region. For the investigated reservoirs, the estimated stock tank oil in place was about 394, 216, 376, and 601 (×10⁶ m³) for AR/E, AR/F, AR/G, and Upper Baharyia, respectively. The projected volumes show the potential of the investigated intervals.

埃及西部沙漠的北部是一个非常有前途的产油省。Abu Sennan油田的Abu Roash和Bahariya组岩性组成多样，导致储层在水平和垂直方向上的连续性存在差异。利用5口井的数据集和覆盖Abu Sennan整个地区的三维地震数据，解决了储层非均质性问题。利用地球物理井资料确定了岩性和储层水平。研究的地层包括砂岩、碳酸盐和页岩。Abu Roash组的“E”和“G”成员，以及Bahariya组，具有最高的含烃潜力。Abu Roash E的净产层范围为17 ~ 47 m，页岩体积范围为17% ~ 36%，有效孔隙度范围为20% ~ 26%，含油饱和度范围为49% ~ 77%。Abu Roash“G”的净产层范围为7-34米，页岩含量为5% - 42%，有效孔隙度为10% - 24%，烃饱和度为46% - 60%。Bahariya组垂向厚度为12 ~ 62 m，页岩含量为16% ~ 44%。地层有效孔隙度为15% ~ 26%，含油饱和度为46% ~ 77%。利用分析后的三维地震数据绘制深度构造图。地震数据解释和岩石物理分析为Abu Sennan地区的构造和储层创建了三维模型。静态模型作为计算体积的主要输入，并在研究区域产生另外两个有趣的机会。对于所调查的储层，AR/E、AR/F、AR/G和Upper Baharyia的储油量分别约为394、216、376和601 （×106 m3）。预测的体积显示了所研究的层段的潜力。

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引用次数: 0

Optimization design of natural gas differential pressure power generation under flow fluctuation 流量波动下天然气差压发电优化设计

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2024.12.004

Xiaohua Zhu , Wenyang He , Qinglong Lei , Quan Liu

“Double carbon” is a two-stage carbon emission reduction goal proposed by China, and differential pressure power generation, as a natural gas (NG) residual pressure energy power generation technology, can effectively utilize natural gas residual pressure energy and also realize zero carbon emission. Aiming at the problem of low efficiency of differential pressure power generation due to the large fluctuation of natural gas flow rate, this paper calculates the potential of differential pressure power generation by using the exergy analysis method and confirms the feasibility of differential pressure power generation. Meanwhile, three optimization schemes are proposed to enhance the efficiency of pressure energy utilization in the purification plant, and economic analysis is used to compare the optimization results. Calculation results show that: when the average flow rate of natural gas is

300 \times 10^{4}

m³/d, the theory of using differential pressure power generation can convert

647.3 \times 10^{4}

kW·h of electric energy per year, while the case's annual power generation is

376.3 \times 10^{4}

kW·h, which accounts for 58% of the theory; optimization results show that: the optimize the duration of power generation scheme, continuous power generation scheme, and high efficiency power generation scheme increase the annual power generation compared to the case by 5%, 9%, and 11%, and the net profit increases by 1.6%, 4.9%, and 10% respectively; therefore, it is feasible to adopt natural gas differential pressure power generation technology in purification plant, in which the payback period of high-efficiency power generation scheme is the shortest, only 3.24 years.

“双碳”是中国提出的两阶段碳减排目标，而差压发电作为天然气余压能发电技术，既能有效利用天然气余压能，又能实现零碳排放。针对天然气流量波动大导致的差压发电效率低的问题，采用火用分析方法计算了差压发电的潜力，确认了差压发电的可行性。同时，为提高净化装置压力能利用效率，提出了3种优化方案，并对优化结果进行了经济分析比较。计算结果表明：当天然气平均流量为300×104 m3/d时，采用差压发电理论每年可转换电能647.3×104 kW·h，而实例年发电量为376.3×104 kW·h，占理论发电量的58%；优化结果表明：优化后的发电方案、连续发电方案、高效发电方案的年发电量比方案分别提高5%、9%、11%，净利润分别提高1.6%、4.9%、10%；因此，净化装置采用天然气差压发电技术是可行的，其中高效发电方案投资回收期最短，仅为3.24年。

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引用次数: 0

A review of the critical conditions required for effective hole cleaning while horizontal drilling 回顾了水平钻井时有效清洗井眼所需的关键条件

IF 4.2 Q2 ENERGY & FUELS

Petroleum

Pub Date : 2025-04-01 DOI: 10.1016/j.petlm.2025.02.002

Amir Shokry Youssef , Ahmed Abdulhamid Mahmoud , Salaheldin Elkatatny , Talal Al Shafloot

Horizontal drilling has become increasingly prevalent in the oil and gas industry due to its potential for enhanced reservoir recovery and reduced environmental impact. However, effective hole cleaning remains a critical challenge in horizontal drilling operations directly impacting drilling efficiency and overall project economics. This review paper aims to comprehensively analyze the critical conditions required for effective hole cleaning in horizontal drilling operations. It investigates the mechanics of cuttings transport within horizontal wells, analyzing the forces at play and various flow patterns. It discusses different methodologies, including empirical correlations, experimental studies, machine learning models, and modeling techniques, used to assess hole cleaning efficiency. Drawing from literature, industry guidelines, and case studies, the study identifies key factors such as fluid properties, wellbore geometry, and drilling parameters influencing hole cleaning efficiency. Challenges such as low annular velocity and complex lithology are highlighted, alongside technological downhole tools innovations. By synthesizing these findings, the paper underscores the importance of addressing these challenges to optimize drilling performance. Serving as a valuable resource for engineers and researchers, it provides insights into optimization techniques and innovations to enhance drilling efficiency in horizontal wellbores, thus facilitating improved operational outcomes.

由于具有提高油藏采收率和减少环境影响的潜力，水平钻井在油气行业中变得越来越普遍。然而，在水平钻井作业中，有效的井眼清洁仍然是一个关键的挑战，直接影响钻井效率和整个项目的经济性。本文旨在全面分析水平钻井作业中有效清洗井眼所需的关键条件。它研究了水平井中岩屑运移的机理，分析了起作用的力和各种流动模式。它讨论了不同的方法，包括经验关联、实验研究、机器学习模型和建模技术，用于评估井眼清洁效率。根据文献、行业指南和案例研究，该研究确定了影响井眼清洁效率的关键因素，如流体性质、井眼几何形状和钻井参数。低环空速度和复杂岩性等挑战，以及井下工具的技术创新都受到了重视。通过综合这些发现，本文强调了解决这些挑战以优化钻井性能的重要性。作为工程师和研究人员的宝贵资源，它提供了优化技术和创新的见解，以提高水平井的钻井效率，从而促进改善作业效果。

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