Petroleum最新文献

{"title":"Rapid screening and optimization of CO2 enhanced oil recovery operations in unconventional reservoirs: A case study","authors":"Shuqin Wen ,&nbsp;Bing Wei ,&nbsp;Junyu You ,&nbsp;Yujiao He ,&nbsp;Qihang Ye ,&nbsp;Jun Lu","doi":"10.1016/j.petlm.2025.03.001","DOIUrl":"10.1016/j.petlm.2025.03.001","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 188-200"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883062","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}

{"title":"Micro- and macroscopic experiments on self-adaptive mobility control and displacement efficiency of carbon-based composite nanofluid for enhanced oil recovery","authors":"Rui Liu ,&nbsp;Jie Deng ,&nbsp;Wanfen Pu ,&nbsp;Yue Li ,&nbsp;Yuanyuan Lu ,&nbsp;Binyang Zou ,&nbsp;M.A. Varfolomeev ,&nbsp;Chengdong Yuan","doi":"10.1016/j.petlm.2025.01.001","DOIUrl":"10.1016/j.petlm.2025.01.001","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 211-225"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883064","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}

{"title":"Development directions of formation damage evaluation and fracturing fluids in tight and shale oil reservoirs","authors":"Lijun You ,&nbsp;Yunsong Xie ,&nbsp;Yang Chen ,&nbsp;Yili Kang ,&nbsp;Chen Huang ,&nbsp;Huaijian Zhai","doi":"10.1016/j.petlm.2025.02.004","DOIUrl":"10.1016/j.petlm.2025.02.004","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 125-142"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883058","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}

{"title":"Predicting water-based drilling fluid filtrate volume in close to real time from routine fluid property measurements","authors":"Shadfar Davoodi ,&nbsp;Mohammed Ba Geri ,&nbsp;David A. Wood ,&nbsp;Mohammed Al-Shargabi ,&nbsp;Mohammad Mehrad ,&nbsp;Alireza Soleimanian","doi":"10.1016/j.petlm.2025.03.002","DOIUrl":"10.1016/j.petlm.2025.03.002","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 174-187"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883060","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}

{"title":"Study on rapid construction of microemulsion system based on EACN of crude oil measured by the direct method","authors":"Yibo Li ,&nbsp;Min Yang ,&nbsp;Tianshuang He ,&nbsp;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}

{"title":"An environmentally friendly and low-cost alginate-based gel for water management in petroleum reservoirs: Characterization and efficacy investigation","authors":"Maede Ayari ,&nbsp;Shahriar Osfouri ,&nbsp;Reza Azin ,&nbsp;Amir Rostami","doi":"10.1016/j.petlm.2025.03.003","DOIUrl":"10.1016/j.petlm.2025.03.003","url":null,"abstract":"<div><div>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, C<img>C, 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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 248-258"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143882921","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}

{"title":"Optimizing heavy crude oil conversion: Catalytic thermolysis with TiO2@α-Fe2O3 nanocomposite and surfactant dynamics","authors":"Asmaa S. Morshedy ,&nbsp;Tahany Mahmoud","doi":"10.1016/j.petlm.2025.02.003","DOIUrl":"10.1016/j.petlm.2025.02.003","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 234-247"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883066","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}

{"title":"Exploring hydrocarbon potential with 3D modeling techniques: Lower Cretaceous formations in Abu Sennan field, north Western Desert","authors":"Taher Mostafa ,&nbsp;Mohamed Reda ,&nbsp;Mohamed Mosaad ,&nbsp;Dmitriy Martyushev ,&nbsp;Mansour H. Al-Hashim ,&nbsp;Mohamed Fathy","doi":"10.1016/j.petlm.2025.03.004","DOIUrl":"10.1016/j.petlm.2025.03.004","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 158-173"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883061","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}

{"title":"Optimization design of natural gas differential pressure power generation under flow fluctuation","authors":"Xiaohua Zhu ,&nbsp;Wenyang He ,&nbsp;Qinglong Lei ,&nbsp;Quan Liu","doi":"10.1016/j.petlm.2024.12.004","DOIUrl":"10.1016/j.petlm.2024.12.004","url":null,"abstract":"<div><div>“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 <span><math><mrow><mn>300</mn><mo>×</mo><msup><mn>10</mn><mn>4</mn></msup></mrow></math></span> m³/d, the theory of using differential pressure power generation can convert <span><math><mrow><mn>647.3</mn><mo>×</mo><msup><mn>10</mn><mn>4</mn></msup></mrow></math></span> kW·h of electric energy per year, while the case's annual power generation is <span><math><mrow><mn>376.3</mn><mo>×</mo><msup><mn>10</mn><mn>4</mn></msup></mrow></math></span> 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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 226-233"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883065","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}

{"title":"A review of the critical conditions required for effective hole cleaning while horizontal drilling","authors":"Amir Shokry Youssef ,&nbsp;Ahmed Abdulhamid Mahmoud ,&nbsp;Salaheldin Elkatatny ,&nbsp;Talal Al Shafloot","doi":"10.1016/j.petlm.2025.02.002","DOIUrl":"10.1016/j.petlm.2025.02.002","url":null,"abstract":"<div><div>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.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 2","pages":"Pages 143-157"},"PeriodicalIF":4.2,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143883059","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}