Day 3 Wed, February 14, 2024最新文献

{"title":"Natural Fracture Modeling in Unconventional Dadas-I Member for 3D Seismic Survey in the Southeastern Turkey","authors":"Artem Orlov, Canalp Özkul, Fethi Bensenouci, Ekrem Yazaroglu, Ahmet Ergun Mengen, Ismail Omer Yilmaz","doi":"10.2523/iptc-23533-ms","DOIUrl":"https://doi.org/10.2523/iptc-23533-ms","url":null,"abstract":"\u0000 Silurian age Dadas-I shale exhibit low porosity and extremely low matrix permeability. Acting as one of the main source rocks in South-East Turkey, it represents a self-sourced unconventional play. This study aims at using an approach spanning from seismic to image log data analysis and 3D geomechanics to develop a discrete fracture network model (DFN) to provide new insights into distribution of hydrocarbons since only developed natural fractures make this reservoir producible.\u0000 The study uses borehole image log data acquired in the Dada»-I interval of 3 exploration wells: X-1, X-6, X-9, 3D seismic and 3D geomechanical model. The main steps of the workflow are: 1).to use interpreted image logs and classify the fractures by fracture sets, 2).to evaluate possible fracture drivers, defined as any 3D properties that can be sensitive to fracture intensity information in the inter-well space, 3).to review this analysis in the context of the seismic structural interpretation and regional tectonic framework, 4).to employ geomechanical model for likelihood of local reactivation.\u0000 The analysis of natural fracture properties, together with petrophysical data, seismic interpretation, and stress regime enable to build a 3D DFN model, predicts fractures occurrence in the Dada»-I interval and used this output for dynamic reservoir modeling. The seismic attributes together with regional geology reveals two major sets of fractures: strike in ESE-WNW that relates to the first extensional tectonic event and the second with a strike NNE-SSW after paleo-stress rotation from E-W to N-S. Application of geomechanical model discloses that not all fractures should be considered as point of weakness. Only discontinuities that are favorably oriented to in-situ stress more likely to be hydraulically conductive. The result of this interpretation were used to predict hydrocarbon flowing zones. Accordingly, the selection of testing intervals on the basis of the highest density of fractures only is not a valid approach to determine prospective zones. In the current strike-slip/compressional regime, the fracture direction and dip is the main control to hydrocarbon flow with the best contribution from natural fractures oriented close to the present day maximum horizontal stress.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527625","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":"Successful Application of Co2 Foam Fracturing Enables Paradigm Shift in Stimulation Strategy of North Kuwait Jurassic Depleted Reservoirs","authors":"Mohamed Abdel, Slb Kholoud Al-Mefleh, Danah Al-Muhanna, E. Fidan, Z. Abdul-Samad, Y. Al-salali, Ayo Ajayi","doi":"10.2523/iptc-23591-ms","DOIUrl":"https://doi.org/10.2523/iptc-23591-ms","url":null,"abstract":"\u0000 The first ever CO2 foam fracturing new technology in Kuwait Oil Company (KOC) history was executed flawlessly in late 2021. Three treatments were executed. Co2 Foam Fracturing proved its significant added value of improving productivity in deep depleted tight carbonate Jurassic reservoirs, enhance flow back, reduce water consumption and carbon emission, and enable early production plus improving operation efficiency and cost saving. The stimulation operation has proven to be a huge success for all multidisciplinary teams involved as preliminary results showed over 50-70% production increase compared to offset wells.\u0000 The main challenges of acid fracturing stimulation in depleted reservoirs are the need for extended formation cleanup to flow back the injected fluids via prolonging Nitrogen lift that add higher operational costs and intervention operations. Therefore, energetic high foam efficiency frac fluid becomes essential to assist flowback and retrieve pumped frac fluids from reservoir. To tackle these challenges, Carbon Dioxide CO2 is pumped in liquid phase as energetic fluid together with normal frac fluids. Due to CO2 liquid nature, high foam efficiency can be reached (40 – 50%) at much lower friction losses. So, it enables achieving pumping frac at high rates and high foam efficiency. The main benefits of CO2 Foam frac are better fracture cleanup due to expansion of the stored compressed gas in the liquid CO2, fluid loss control that is provided by foam, minimized fracture conductivity damage, and the increase in hydrostatic pressure while pumping that translates to lower surface pressures during injection.\u0000 The selected pilot well is in depleted deep tight carbonate reservoir area of North Kuwait Jurassic gas fields. The executed acid fracturing operation required close planning starting from Q1-2021. Many challenges faced from logistical issues, lack of infrastructure and CO2 resources for the multi-faceted operation due to COVID-19 pandemic limitations. These challenges were tackled ahead with the integration of technical and operations teams to bridge the knowledge gap and to enable executing the operation safely.\u0000 The pilot well’s net incremental production gain is estimated at 50-70% compared to offset wells, with improved flowback and formation cleanup with less well intervention. The resulting time and cost savings as well as the incremental well productivity and better operation efficiency confirmed high perspectives for the implemented foam acid fracturing approach. Another two CO2 Foam acid fracturing wells were executed with good results too.\u0000 This paper will demonstrate the value of CO2 foam fracturing in depleted reservoir and KOC experience post first application and its plans to expand CO2 Foam Fracturing application across KOC different fields.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"9 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527873","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 New Numerical Well-Test Model Using an Analytically Modified Embedded Discrete Fracture Model","authors":"Biao Zhou, Zhiming Chen, Zhigang Song, Xurong Zhao, Bin Wang, O. Olorode","doi":"10.2523/iptc-24441-ms","DOIUrl":"https://doi.org/10.2523/iptc-24441-ms","url":null,"abstract":"\u0000 In the past few decades, multi-stage hydraulic fracturing technology has emerged as a crucial tool for the commercial development of unconventional oil and gas resources. Accurately characterizing transient flow near fractures is a critical concern for many researchers. Currently, discrete fracture models (DFMs) are primarily used to analyze the pressure transient behaviors of multi-stage fractured horizontal wells (MFHWs). Although discrete fracture models can accurately capture transient flow around fractures, they require a substantial number of grids to ensure computational precision, which in turn leads to higher computational costs. Conversely, standard embedded discrete fracture models (EDFMs) based on pseudo-steady-state assumptions, while computationally efficient, struggle to precisely depict the early transient flow around fractures. To narrow this gap, we proposed a new numerical well-test model for analyzing the pressure transient behaviors of MFHWs using structured Cartesian grids and an analytically modified EDFM (AEDFM).\u0000 We have made modifications to the transmissibility between the matrix and fractures by multiplying it with a transient factor. Furthermore, we have validated the accuracy and efficiency of our proposed model through comparisons with results from analytical models and standard well-test software. This demonstrates the significance of our proposed model in accurately capturing transient flow around fractures and reducing computational costs. Additionally, we conducted research on the pressure transient behaviors of a MFHW under different parameters and further evaluated the significance of the proposed modifications based on the results. The results indicate that, compared to the standard EDFM, the AEDFM can effectively match the early nonlinear pressure drop near fractures. This study may potentially provide a powerful tool for the precise analysis of pressure transient behaviors in MFHWs, while also significantly reducing computational costs.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"22 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528011","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":"PTA Application in Carbon Capture and Storage – Challenges, Diagnostics, Modeling","authors":"E. H. Idorenyin, I. M. Al-Abdulwahab","doi":"10.2523/iptc-24440-ms","DOIUrl":"https://doi.org/10.2523/iptc-24440-ms","url":null,"abstract":"\u0000 This paper documents pressure transient analysis (PTA) aspects of carbon capture and storage (CCS), from design considerations through modeling while also highlighting attendant challenges. CO2 injection in porous media has expanded in utility and increased in popularity following global consensus on decarbonization. To this end, CCS is unarguably a viable decarbonization option for the petroleum industry. However, it requires a reliable understanding of the subsurface in terms of quality, integrity, and capacity. In this study, we expatiate on the place of PTA analysis in long-term CO2 storage in porous media.\u0000 This work focuses on CO2 injection in saline aquifers; nonetheless, findings here can be easily adapted to depleted oil and gas systems. We first discuss CO2 injection-falloff test design vis-à-vis expectations from PTA-driven formation description. This is followed by an overview of analysis techniques that guarantee reliable estimate of injectivity and robust characterization. We then demonstrate the use of transient modeling to obtain a first-level evaluation of storage capacity in addition to improved characterization. The challenges encountered are also discussed.\u0000 Our findings show that knowledge of potential storage sites is indispensable in successful CO2 sequestration. A properly designed and carefully implemented well test remains a viable window to acquiring representative dynamic data which, upon analysis, provides valuable information about the storage media. Diagnostics and modeling must be supported with accurate description of the injection fluid as well as the in-situ formation fluid, otherwise the results may be in serious error.\u0000 This paper provides guidance toward best practices on the design, diagnostics and modeling of CO2 injection-falloff tests for the purpose of robust formation description and long-term CO2 sequestration.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"49 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527983","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 Simple Yet Impactful Innovation to Optimize Production of Low-Quality Reservoir (LQR) by Using a Modified Venturi Choke, Pilot Case at Matured Waterflood Field Bravo, Central Sumatera Basin","authors":"Ade Fadli, Aulia Rahman, Daniel Hadi Putranto, Cintani Kusuma Dewi, Muhammad Saeful Nurjaman, Iftikar Luthfi Ramadhan, M. Afton","doi":"10.2523/iptc-23547-ms","DOIUrl":"https://doi.org/10.2523/iptc-23547-ms","url":null,"abstract":"\u0000 In a mature asset like Bravo field in Central Sumatera Basin, the ‘easy to produce’ oil is becoming increasingly rare and hard to find. Therefore, pursuing oil at the low-quality reservoir (LQR) has become one of the main focuses nowadays. Despite having huge potential due to its low recovery nature, optimizing LQR production comes with set of challenges. This paper highlights a successful innovation to unlock the LQR potential, offering a solution to maximize production.\u0000 The innovation involves the application of a modified venturi choke (VC). Basic principle of this method is producing the LQR zone (low rate, low watercut) with the assist from a better-reservoir quality zone below, namely High-Quality Reservoir (HQR) zone (high rate, high watercut). Unlike the conventional commingle approaches, the modified VC is strategically placed between the zones, applying fluid restriction to the HQR zone. Acting as a downhole choke, it induces a substantial pressure drop, resulting in a jetting effect that efficiently strips out fluids from the LQR zone, thereby enabling optimal oil production contribution.\u0000 Pilot execution on the first 2 wells in Bravo Field successfully delivered 100 BOPD incremental oil gain, proven that this newly developed method is working very well. The installation of the venturi choke (VC) has led to a substantial improvement in oil contribution from the LQR zone, a fact confirmed through oil finger printing analysis. Notably, the LQR zone, which was theoretically unable to produce even with the smallest pump and would not contribute significantly through conventional commingle methods, has demonstrated its production potential using this approach. The established flow process and screening criteria are also proven effective to capture potential candidates that cannot be produced with traditional commingle methods. Comprehensive analysis of historical production data, swab tests, G&G interpretation, reservoir simulation, and well modeling played a pivotal role in selecting the most suitable LQR candidate for this optimization. Additionally, considering VC material is available at relatively large quantities on hand, makes it feasible to implement the same approach in numerous other LQR potentials within the field and the surrounding region. This scalability further highlights the benefit of this method in unlocking LQR potential beyond the initial pilot wells.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"11 11","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528207","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":"Integration of Rock Typing and Neural Network Techniques for Accurate Permeability Prediction in Heterogeneous Carbonate Reservoirs: A Case Study from Abu Dhabi Offshore Field","authors":"E. Elabsy, Ahmed Soliman, Lichuan Deng, Sundos Al Abed, Hiroki Montani, Maddiah Al Suwaidi","doi":"10.2523/iptc-23411-ms","DOIUrl":"https://doi.org/10.2523/iptc-23411-ms","url":null,"abstract":"\u0000 Permeability prediction or calculation in heterogeneous carbonate formations is a challenging task due to the complexity of the rock properties and pore systems that are difficult to characterize accurately. In this study an innovative and efficient approach developed and used to overcome this challenge by combining rock typing and machine learning neural network (MLNN) techniques to accurately predict the permeability of heterogeneous carbonate formations.\u0000 The supervised machine learning approach based on a neural network algorithm trained on a large dataset of offset wells data. The input data for the algorithm included various rock properties from core and well logs analysis data. The output of the algorithm was a prediction of rock types and their corresponding permeability values based on the porosity and permeability equations. The MLNN model was trained using a backpropagation algorithm and validated using an independent dataset to ensure the accuracy and reliability of the results. The trained model was then used to predict rock types and permeability values for new wells.\u0000 The results of the study showed that the approach of using rock typing and machine learning neural network outperforms other traditional methods in predicting permeability in heterogeneous carbonate formations. The predicted permeability values were validated against actual measurements from core data and formation testing mobility, and the results showed a good correlation between predicted and measured values and demonstrating the model reliability. The use of rock typing provides a more accurate characterization of the reservoir and helps to improve the prediction of permeability. The study also revealed that the rock types and permeability values varied significantly across the carbonate formation, and the neural network model was able to capture this heterogeneity accurately by learn the complex relationships between the rock types and petrophysical properties, which resulting in improved permeability predictions. The predicted permeability values were used to generate permeability maps that helped identify areas with higher permeability values, which can be targeted for well placement to improve hydrocarbon recovery.\u0000 This approach lies in the integration of rock typing and machine learning neural network to predict permeability in heterogeneous carbonate formations. This method provides an innovative solution to the challenges associated with traditional methods, which often fail due to the complex nature of carbonate reservoirs. The approach is applicable to a wide range of carbonate formations, and has the potential to significantly improve reservoir characterization and production optimization.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527799","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":"Quantitative Evaluation and Prevention Technology of Microbiologically Influenced Corrosion Under Deposit in a Middle East Carbonate Oilfield","authors":"Zheng-rong Ye, Guan Wang, Xiang Zhou, Weidong Jiang, Ran Yi, Xiaodong Cui, Z. Qiu, Zhiwen Yang","doi":"10.2523/iptc-24636-ms","DOIUrl":"https://doi.org/10.2523/iptc-24636-ms","url":null,"abstract":"\u0000 Water flood development mode was adopted to enhance oil recovery in a Middle East carbonate oilfield. The injected water is a mixture from the produced water and clear water. The water quality of the injected water basically meets the requirement standards except that total sulfide content is about 100mg/L. However, the water injection system has still encountered severe microbiologically influenced corrosion perforation and scaling blockage after less than 2 years, which affects the crude oil production in the oilfield.\u0000 This paper aims to find out the mechanism of microbiologically influenced corrosion under deposit, and propose the prevention strategy. The maximum likelihood estimation (MPN) and fluorescent staining methods are applied to study the enrichment change of sulfate-reducing bacteria (SRB) under deposit. And then the synergistic effect of scale and SRB on uniform and localized corrosion was quantitatively evaluated using methods such as weight loss test, potentiodynamic polarization curve, white light interferometer, and scanning electron microscopy. On this basis, the electrochemical test and surface analysis methods are used to optimize the integrated inhibitor system for corrosion, scale inhibition, and sterilization.\u0000 The results show that the number of SRB under deposit reached the peak value of about 2×108 cells/mL after 7 days, which is nearly one order of magnitude more than the number of SRB floating in the solution. It was clear that SRB is significantly enriched in the deposit. The synergistic effect between deposit and SRB can significantly accelerate the corrosion of carbon steel. The contribution of synergistic effect to uniform corrosion and localized corrosion of carbon steel is as high as 70% and 50% respectively. The synergistic effect of deposit and SRB on corrosion is mainly the promotion of under-deposit corrosion and the acceleration of microbiologically influenced corrosion. The S type small molecular weight corrosion inhibitor and its composite system have excellent anti-corrosion effects under scale, with a corrosion inhibition efficiency of 90%. After on-site application, the corrosion perforation rate is reduced more than 80%.\u0000 This study provides useful practical experience to mitigate under-deposit SRB corrosion of high salinity and high acidity water injection systems.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"10 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528213","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":"Advancing Relative Permeability and Capillary Pressure Estimation in Porous Media through Physics-Informed Machine Learning and Reinforcement Learning Techniques","authors":"Ramanzani Kalule, H. Abderrahmane, S. Ahmed, A. M. Hassan, W. Alameri","doi":"10.2523/iptc-23572-ms","DOIUrl":"https://doi.org/10.2523/iptc-23572-ms","url":null,"abstract":"\u0000 Recent advances in machine learning have opened new possibilities for accurately solving and understanding complex physical phenomena by combining governing equations with data-driven models. Considering these advancements, this study aims to leverage the potential of a physics-informed machine learning, complemented by reinforcement learning, to estimate relative permeability and capillary pressure functions from unsteady-state core-flooding (waterflooding) data. The study covers the solution of an inverse problem using reinforcement learning, aiming to estimate LET model parameters governing the evolution of relative permeability to achieve the best fit with experimental data through a forward problem solution. In the forward problem, the estimated parameters are utilized to determine the water saturation and the trend of capillary pressure. The estimated curves portray the relationship between relative permeability values and saturation, demonstrating their asymptotic progression towards residual and maximum saturation points. Additionally, the estimated capillary pressure trend aligns with the existing literature, validating the accuracy of our approach. The study shows that the proposed approach offers a promising method for estimating petrophysical properties and provides valuable insights into fluid flow behaviour within a porous media.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"401 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528404","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":"Intermittent Pumping Optimization for Ultra-Low Permeability Reservoirs Sampling","authors":"Shiyue Wang, Zhaoya Fan, Guang Rao, Wei Xiang, Rui Qin, Jun Sun, Bonan Ren, Zhiwen Liu, Aydar Galiev, Amr Ismail","doi":"10.2523/iptc-24464-ms","DOIUrl":"https://doi.org/10.2523/iptc-24464-ms","url":null,"abstract":"\u0000 At present, the low-permeability reservoir fluid identification and formation dynamic evaluation mainly relies on the wireline formation test (WFT) technology in China Offshore exploration (Yang 2014 and Zhang 2018). However, because of low permeability, formation fluids cannot be continuously supplied while sampling, which makes it impossible to achieve continuous pumping during sampling operations. Therefore, there are problems such as low success rate and poor timeliness in the sampling operation of low to ultra-low permeability reservoirs. In some extreme cases, formation fluids samples cannot be obtained, which increases operating costs and exploration risks.\u0000 As a spare and passive sampling method, intermittent pumping is often used for fluid identification and sampling in ultra-low permeability reservoirs. However, at present, there is no systematic analysis and demonstration of the application limit and related feasibility of intermittent pumping in the industry, nor the scientific optimization of intermittent pumping. The rationality of the intermittent pumping scheme affects the efficiency and sampling success rate. This paper aims to find out the influencing factors of intermittent pumping, and to form the optimal intermittent scheme to guide the operation. This paper uses the Modular Formation Dynamic Tester Tool (MDT) formation testing tool as the research object. First, the lower limit of MDT was analyzed. Second, through numerical simulation, the pressure recovery ratios (flowing pressure at the end of pump stop/formation pressure) of 40%, 50%, 60%, 70%, 80%, 90% were respectively defined; 8 in-, 15 in-, 20 in- invasion depths were simulated, which represent shallow, middle, and deep-mud filtrate invasion scenarios, respectively. Three samples of purity at 20%, 50%, and 80% were set as achievement goals; a total of 54 kinds of \"intermittent\" pumping operations were simulate, and the total operation time in the corresponding situations were obtained as well.\u0000 During intermittent pumping, the continuous invasion of mud filtrate is the key factor affecting the pumping time and samples assurance. In this study, the mud filtrate invasion rate of different formations and mud systems was confirmed through laboratory and previous WFT data analysis. Moreover, this paper realized the world's first numerical simulation about intermittent pumping while there was mud filtrate continuous invasion. The intermittent pumping performance under different original invasion depths and different continuous invasion rates were also simulated and analyzed to provide guidance for the optimization of subsequent operations.\u0000 Through the above studies, the optimized intermittent pumping method has been successfully applied to ultra-low to low permeability reservoir WFT sampling in multiple wells, which in the past could only be abandoned or it had to rely on advanced tools.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528170","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":"Maximizing Profitability Through Automated Production Optimization: A Game-Changer for Digital Oil Field Operations in Kuwait Integrated Digital Field (KwIDF)","authors":"H. AL-Rashidi, K. Ranjan, R. Lara, B. Muhsain, S. Singh, D. Tripathi","doi":"10.2523/iptc-23592-ms","DOIUrl":"https://doi.org/10.2523/iptc-23592-ms","url":null,"abstract":"\u0000 The paper outlines a comprehensive workflow for calibrating well models and optimizing well production. An automated well-model management system ensures data accuracy and timeliness by fetching information from the production database. Simultaneously, the well-production optimization process identifies opportunities for improving field development and production operations by analyzing real-time data and applying optimization techniques. The system empowers engineers with data-driven decision-making tools and provides recommendations for optimizing well parameters. The integration of multiple data sources, automated processes, and data quality control ensures the reliability of results. This automated approach enhances the identification of valid optimization opportunities and facilitates well performance management, leading to significant oil production gains and informed decision-making within the field.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"34 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528172","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}