Day 1 Mon, February 12, 2024最新文献

{"title":"A Data-Infused Methodology for Estimating Swelling Potential in Shales Exposed to Various Completion Fluids","authors":"M. Khan, Zeeshan Tariq, M. Murtaza, Bicheng Yan, M. Kamal, Mohamed Mahmoud, Asiya Abbasi","doi":"10.2523/iptc-24100-ms","DOIUrl":"https://doi.org/10.2523/iptc-24100-ms","url":null,"abstract":"\u0000 Formation damage in reservoirs poses a recurring challenge throughout the phases of drilling, completion, and production, significantly impeding efficiency and diminishing resource extraction in oil and gas development. This detrimentally affects production capacity, leading to potential reservoir shutdowns and hindering the timely discovery and development of oil and gas fields. The water-based drilling fluids are mixed with various swelling inhibitors; nevertheless, shale swelling could still take place during the completion phase as these fluids do not usually consider this phenomenon. To quantify the swelling inhibition potential of drilling/completion fluids, several laboratory experiments are usually carried out. These experiments are costly, time-consuming, and tedious. This study used machine learning technique to predict the dynamic linear swelling of shale wafers treated with different types of completion fluids containing varying inorganic salts such as NaBr, CaBr2, and NH4Q.\u0000 A comprehensive experimental investigation was conducted to gather datasets suitable for training machine learning model based on various completion fluid constituents. The study involved utilizing a dynamic linear swell meter to quantify swelling inhibition potentials, assessing sodium bentonite clay wafers' responses to all completion fluid solutions through linear swell tests lasting 24 to 48 hours. Additionally, the study measured zeta potential and conductivities across solutions with different concentrations. Leveraging sequential data and memory cell architectures, the research developed an LSTM (Long Short-Term Memory) machine learning model aimed at predicting and comprehending swelling behaviors within specific contexts. This model was trained using input parameters such as zeta potential, salt conductivity, salt concentrations, density, and elapsed time, while the model output represented dynamic linear swelling in percentage.\u0000 This intelligent technique can be used to guide and streamline laboratory experiments to determine dynamic linear swelling of shales. It can serve as a quick tool to guide fluid engineers at the rig site to delineate shale swelling reasons pre-, post-, and during completion operations. Consequently, operators will be better prepared to deal with unknown swelling issues that lead to NPT in operations.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"53 10","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527604","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":"From Lab to a Successful Field Operation: In-Situ Polymer Gel with Adsorption System for Water Shutoff Application","authors":"A. Almohsin, H. Sharma, M. Alabdrabalnabi, W. Kharrat","doi":"10.2523/iptc-24065-ms","DOIUrl":"https://doi.org/10.2523/iptc-24065-ms","url":null,"abstract":"\u0000 Robust and cost-effective water shutoff technologies are required to improve oil recovery and avoid challenges such as undesired water production. Herein, we present a new chemical water shutoff technology: A composite polymer gel system for carbonate substrate formation, from research work to successful field implementation.\u0000 The composite gel with controlled gelation time was developed to isolate water production zones over various parameters, including temperature, pressure, injectivity duration, and flow rate. The rheological property of matured gels was investigated, such as the storage modulus (G'). In addition, a robust process was implemented based on rigorous job design and preparation, precise execution with real-time downhole monitoring, and thorough post-job analysis. Indeed, production logging and a noise tool were run to confirm the water entry and ensure good cement isolation behind the casing across the target zone.\u0000 Laboratory results revealed that the gelation time can be controlled by varying the amount of fluid component, allowing a predictable pumping time at the given temperature between minutes to more than 10 hours. The gel system showed a significant pressure increase after the treatment, with good durability and effective water shut-off during the extended core flooding experiment. Thus, it is in alignment with gel strength testing. Hence, during the job mix adequate formulations based on the real-time downhole temperature, recorded while simulating the formation cooldown during treatment squeeze between retrievable plug and inflatable packer. The bottom hole circulating temperature and pressure were then measured in real time to adjust the water shutoff fluid formulations and to avoid exceeding the differential pressure limitation of the inflatable packer. After squeezing and waiting on the gelation of the water shutoff fluid in three stages, a successful pressure test demonstrated that the high water cut zone is reduced. Analysis of the pre and post job through rate test using downhole production logging tool (PLT); confirmed the success of treatment with a significant reduction in water production for more than 60%.\u0000 The new trend of using in-situ composite gel incorporated with adsorption system is a breakthrough water shutoff technology. Utilizing laboratory coupled with field data collected before, during, and after gel injection along with proper diagnostic are the key elements to increase the success rate.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527639","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":"Cuttings Accumulations Prediction in Deviated & Horizontal Wells with Dimensionless Data-Driven Models","authors":"M. Khaled, M. Khan, A. Barooah, Mohammad Azizur Rahman, A. R. Hasan","doi":"10.2523/iptc-24001-ms","DOIUrl":"https://doi.org/10.2523/iptc-24001-ms","url":null,"abstract":"\u0000 Effective cuttings removal in deviated and horizontal wells is essential for improving drilling efficiency and preventing non-productive time (NPT) caused by hole-cleaning issues. While various numerical models have been developed to simulate cuttings accumulation in wellbores, only a subset of these models can be employed for real-time operations due to their complexity and lengthy computational requirements. This paper compares the performance of various data-driven (machine learning) models in monitoring cuttings bed accumulation in real-time during drilling operations.\u0000 The construction of these data-driven models relies on the analysis of hundreds of bed height measurements obtained from ten flow loops. These models incorporate unique dimensionless parameters and are trained on a diverse dataset encompassing a wide range of drilling conditions. These conditions include variables such as the rate of penetration (ROP), drilling flow rate, drillstring rotation, hole eccentricity, wellbore hydraulic diameter and inclination, drilling fluid rheological parameters, and cuttings (solid) density and size. Five different data-driven models are evaluated: linear regressor (LR), deep neural networks (DNN), support vector regressor (SVR), random forests (RF), and extreme gradient boosting regressor (XGBoost) algorithms. Additionally, the performance of the developed models is assessed against previously unseen datasets to ensure fair evaluation. Comparisons are also made with the Duan correlation (a mechanistic model) to evaluate the accuracy and limitations of the data-driven models.\u0000 A total of ten dimensionless parameters are devised to estimate bed height accumulation using the Buckingham-Π theorem and Pearson correlation. The results indicate that both the RF and XGBoost models exhibit accurate estimations of bed thickness, achieving root mean square error (RMSE) and mean absolute percentage error (MAPE) values around 0.07 and 13%, respectively. Furthermore, these two models demonstrate strong generalization capabilities and precision in estimating bed thickness, with a MAPE below 20% when validated against unseen datasets and compared to the Duan model. In contrast, the DNN model is observed to be less accurate than the RF and XGBoost models, though a majority of its predicted points still fall within the ±20% tolerance envelope. On the other hand, both the SVR and LR models exhibit poor accuracy in capturing the underlying relationship between input parameters and the target variable, as evidenced by their scattered residual values. Utilizing the Shapley additive explanations (SHAP) approach and RF feature analysis, the study identifies the Froude number as having high feature importance while negatively impacting bed height predictions. Conversely, the inlet feed concentration and annular eccentricity significantly positively contribute to bed height prediction.\u0000 In conclusion, the data-driven (machine learning) models developed in this study ","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"231 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527904","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":"Assessing the Performance of Thermally Active Polymer as an In-Depth Conformance Technology in a Mature Waterflooded Reservoir: A Recent Field-Scale Case Study Utilizing Interwell Tracers in Argentina's Largest Oil Producing Field","authors":"Mahdi Kazempour, Rodrigo Santamaria, Leonel Lizarazo, J. Gomez, A. Iuliano, C. Martínez, Diego Damian Fernandez","doi":"10.2523/iptc-23996-ms","DOIUrl":"https://doi.org/10.2523/iptc-23996-ms","url":null,"abstract":"\u0000 Waterflooding has been a widely practiced method globally for numerous years, and it has been proven in the field to effectively enhance oil recovery in oil-bearing reservoirs, surpassing primary production methods. Despite its considerable potential for boosting oil recovery, waterflooding faces several challenges that can impede its performance, including reservoir heterogeneities, reservoir structural complexities, and unfavorable mobility ratios. Over the past five years, an extensive multidisciplinary effort has been undertaken to address these waterflood challenges and enhance waterflood sweep efficiency in Argentina. As a result, a cutting-edge conformance technology called Thermally Active Polymer (TAP), also known as BrightWater®, has been successfully implemented in Cerro Dragon, one of Argentina's largest oil-producing fields, yielding encouraging outcomes.\u0000 To assess the efficacy of TAP as a reservoir-triggered conformance agent, two sets of interwell tracer tests (IWTT) were conducted: one before TAP injection and another after TAP injection when an oil response was detected. These IWTTs represented the first instance of flow pattern change identification within the targeted segment of the reservoir. Additionally, they enabled the quantification of transit time changes subsequent to the in-depth conformance treatment. The study also revealed the establishment of new communication paths while the previously existing paths became less active following TAP placement.\u0000 The results obtained from the IWTT tests aligned remarkably well with the expectations derived from conceptual numerical modeling. Furthermore, a distinct correlation was observed between the changes in sweeping profiles observed through tracers and the oil and water production responses on the production side. This confirmed that the thermally active polymer reduced the flow capacities of thief zones, thereby allowing previously unswept segments of the reservoir to come into greater contact with the injected water.\u0000 The findings of this study hold significant implications for the effective execution and design of in-depth conformance treatment programs. Moreover, the study equips end users with quantitative tools for more detailed post-monitoring performance evaluation. TAP has emerged as one of the most widely practiced in-depth conformance technologies for both onshore and offshore applications due to its short execution times, small treatment slug sizes, and ease of injection under various reservoir conditions.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"181 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528454","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":"Enabling Autonomous Well Optimization by Applications of Edge Gateway Devices, Automatic Fluid Level Analyzer and Analytical Dashboards","authors":"Manish Kumar, N. Varma, Manjunath Rao, Ravi Chandak, Sujit Jadhav, Himshella Sharma, Joy Singhal, Amit Ranjan, Shailesh Chauhan, A. Bohra, Atul Patni","doi":"10.2523/iptc-24007-ms","DOIUrl":"https://doi.org/10.2523/iptc-24007-ms","url":null,"abstract":"\u0000 The task of monitoring data in a substantial oil field, devoid of a digital platform, is a formidable challenge. However, it is of paramount importance in the context of Artificial Lift System (ALS) monitoring and optimization. In particular, for sucker rod pumping wells, the real-time collection and analysis of dyna cards assume critical significance. This process provides essential insights into downhole pump behavior and the overall system's health. The current practice of manual dyna card collection, occurring twice a week for approximately 47 horizontal wells, is notably infrequent, given the imperative need for real-time dyna card data, which necessitates a minimum frequency of 256 data points per minute. The analysis of such data proves exceptionally effective in the endeavor to optimize well production and enhance the longevity of both pumps and rod runs. The absence of real-time monitoring has, regrettably, led to well downtime and associated production losses.\u0000 To address this issue, the amalgamation of Internet of Things (IoT), cloud computing, and machine learning has been introduced, thereby transforming our approach from a reactive to a proactive stance. This digital transformation has played a pivotal role in ALS optimization and has contributed significantly to mitigating production losses.\u0000 The data is seamlessly transmitted to the Se Suite Central, a web-based Decision Support System hosted on the cloud. Given the sheer volume of dyna cards generated daily, the system has been equipped with an algorithm leveraging automated card classification, incorporating computer-driven pattern recognition techniques. The real-time data is harnessed for analysis, encompassing basic statistical methods and machine learning algorithms designed to classify thousands of dyna cards each day. Machine learning libraries have been employed to identify distinct pump signatures, subsequently categorizing them. Multiple informative dashboards have been meticulously developed to facilitate rapid analysis of ALS performance, including, but not limited to: Well Operational StatusDyna Cards Interpretation ModuleSucker Rod Pump (SRP) Parameters VisualizationMachine Learning Model Calibration ModulePump Performance Statistics\u0000 Accumulating a substantial volume of data and harnessing domain-specific knowledge, these insights have been instrumental in driving ALS optimization efforts.\u0000 Moreover, intelligent alarm systems have been deployed, drawing on statistical and machine learning settings. These systems promptly issue email alerts when anomalous behavior or erratic dyna cards are identified. This proactive approach has resulted in a reduction in well downtime during select events that were previously addressed reactively. The fusion of domain expertise with digitalization has empowered decision-makers to take informed and efficacious actions. This project has exemplified its capability in remotely managing an asset encompassing over 47 wells, all while o","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"167 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527752","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 Treatment in Water Control with Relative Permeability Modifiers for HP/HT Carbonates","authors":"José María Petriz, Luis Alejandro García, Erick Acuña, Iván Ernesto Narváez, Sarai Santos, L. Eoff, Julio Vasquez Estrada, Iván López","doi":"10.2523/iptc-23950-ms","DOIUrl":"https://doi.org/10.2523/iptc-23950-ms","url":null,"abstract":"\u0000 One of the main problems in the decline of the production of any field is associated with the presence of fractional flow of water and its detrimental effect on the wells. This situation has led to a whole field of study regarding the understanding of this phenomenon, aimed at mitigating this through the application of several technologies and best reservoir management practices.\u0000 This paper will present the analysis, development and results obtained from the application of a relative permeability modifier (RPM) in a naturally fractured carbonate reservoir under high pressure and temperature conditions (HP / HT). This is in addition to a series of so-called \"high potential\" interventions, whose production benefits result in a profitable business case applying an optimized shut-in time strategy in high production wells.\u0000 Finally, a summary with various results of the application of the RPM in different wells will allow broadening the criteria of its application. Although there are cases of success, there will be others in which a better diagnosis must be made to ascertain its effectiveness in the short or medium term, which may be related to the identification of the preferential means of flow in a naturally fractured reservoir, which by its nature, results in a technical-technological challenge, both in its identification and discretization as well as in the field applications.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"8 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527875","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":"Improving Multiphase Flowmeter Accuracy for Hydrocarbon Allocation and Wet Gas Production of Unconventional Oil-Gas Wells","authors":"M. Fiore, M. A. B. Razali, T. Zhang, K. Yang, G. Jolivet, L. Husoschi, J.-P. Hussenet","doi":"10.2523/iptc-23942-ms","DOIUrl":"https://doi.org/10.2523/iptc-23942-ms","url":null,"abstract":"\u0000 Unconventional resource development has become the most widespread form of energy production in the US and has gained increased interest in the Kingdom of Saudi Arabia (KSA). Reliable and robust multiphase flowmeters (MPFMs) using a combination of Venturi and multi-energy gamma-ray absorption represent a solution that can replace bulky and costly separators while providing accurate flow rate monitoring for high gas production. A high accuracy is required, particularly the US where, for the exploitation of mineral resources, landowners receive royalties calculated from the declared hydrocarbon production under their property. Although MPFMs using multi-energy γ-ray absorption cover the full range of gas-volume fraction (GVF) and water-liquid ratio (WLR), production from gas-lift and wet-gas unconventional wells typically features a GVF > 95% and high WLR, which are challenging conditions for achieving the oil flow-rate accuracy required for fiscal allocation.\u0000 By advantageously modifying the MPFM radioactive source, the X-ray fluorescence (XRF) phenomenon generates a lower-energy X-ray emission in addition to those naturally emitted by the source radionuclide. The enhanced sensitivity to differentiating the oil-water droplets in a large gas volume reduces more than twice the WLR measurement uncertainty at high GVFs, thus significantly improving the gas and oil flow-rate accuracies. Proper extraction of fluorescence X-ray emissions is achieved with a full energy spectrum analysis by a dedicated proprietary data-processing algorithm. The new X-ray mode starts from a GVF ∼ 85% due to the large absorption by oil-water liquids. For lower GVFs, the higher-activity XRF source also leads to a small accuracy improvement. Extensive validation by flow-loop tests demonstrates the WLR uncertainty reduction over the entire GVF range, with more than twice reduction at GVF > 95% when compared to the MPFM with an existing source. The update of the nuclear interpretation model leads to a large accuracy improvement of the flow rates. The field exposure of the MPFMs equipped with the new XRF source demonstrates the simple retrofit of the existing deployed flowmeters and the significant improvement of WLR and flow rates, even under gas-lift slug-flow conditions. The high-accuracy XRF-source MPFM can lead to an increased new technology adoption in the US by replacing traditional bulky test separators equipped with natural gas-driven valves. The emission reduction of greenhouse gas will help US oil companies towards achieving their sustainability goals. In KSA, the high-accuracy MPFM can help the energy transition through natural gas, employed in blue hydrogen production.\u0000 This paper describes the details of the new XRF radioactive source and the XRF energy spectrum interpretation that attain high flow rate accuracy even for high GVFs during production from gas-lift and wet-gas unconventional wells. Successful cases in both the laboratory and field conditions validate","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"101 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527951","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 Novel Method for Accurate Measurement of Fluid Saturation in Shaly Sandstone During CO2 Sequestration","authors":"Jidong Gao, Bin Yuan, Wei Zhang, Hongbin Zhang","doi":"10.2523/iptc-23634-ms","DOIUrl":"https://doi.org/10.2523/iptc-23634-ms","url":null,"abstract":"\u0000 Accurate monitoring of fluid saturation is crucial for preventing fingering or leakage during CO2 sequestration. Due to the difficulty in testing the cementation factor of shaly sandstone, the evaluation of fluid saturation in such reservoirs by the Archie equation may be significantly biased. This study presents modifications to the Rhoades capillary bundle model and the Waxman-Smits parallel model for the clay conductivity phase and cementation exponent, based on the principle of the best conduction pathway. we use two different conductivity models and fluid transport coefficients in rock pores to modified the cementation coefficient. We compare different conductivity models and refine them by fitting them to on-site CO2 storage monitoring data. We analyze the impact of parameter variations on conductivity and saturation, and verify the accuracy of the equation. It is found that the relative error of the modified model is 10.76% compared with the conductivity of the dual-water model. Shaly sandstone reservoirs are characterized by clay-water expansion phenomena, with clay conductivity comprising the predominant fraction of total conductivity. The variation in water phase transmission and conductivity can be divided into two phases. In the first phase, conductivity experiences a rapid increase, while in the second phase, it rises gradually in a linear fashion. In shaly sandstone reservoirs, the relative error of the modified model is 5.44%. The enhanced accuracy in saturation calculations serves as a safeguard against measurement errors by on-site engineers.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"87 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527954","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":"Modification of Shale Inhibition Properties using Novel Drilling Fluids with Gemini Surfactant and Associative Polymer as Additives","authors":"H. M. Ahmad, A. Javaid, N. Baig, S. Yasin, T. Iqbal","doi":"10.2523/iptc-23794-ms","DOIUrl":"https://doi.org/10.2523/iptc-23794-ms","url":null,"abstract":"\u0000 Drilling fluids are known as specialized fluids to modify rheology, filtration, fluid loss control, and shale inhibition properties for drilling applications in the oil and gas industry. Various additives are employed to change the properties based on the requirements of the drilling well and to meet the objectives of the drilling process. Additives such as polymers are used for rheology modifiers, fluid loss control modifiers, and shale inhibition control modifiers. Apart from polymers, a novel class of Gemini surfactants is also employed to modify the shale inhibition characteristics. In this work, a combined effect of polymer and Gemini surfactant was studied on the shale inhibition characteristics.\u0000 Various drilling fluid formulations were prepared by adding 0.25 to 0.4% concentration of associative polymer and 0.25% concentration of Gemini surfactant. All the drilling fluids were prepared based on the American Petroleum Institute standards. Two major tests were performed to investigate the effectiveness of prepared drilling formulations for shale inhibition properties. These tests include steady shear rheology and linear swelling tests in the presence of real samples of shale pallets.\u0000 The rheology of drilling fluids including polymer solutions and polymer surfactant solution was measured over a wide range of shear rates ranging from 0.1 (1/s) to 1000 (1/s). The shear stress and viscosity of the polymer solution increased by increasing the concentration of the polymer. However, the shear stress and viscosity of polymer solutions are slightly affected with the addition of surfactant solutions. It was observed that high-concentration polymer solutions were less likely by the surfactant solution. The linear swelling tests were performed with pure polymer and surfactant solutions along with the polymer-surfactant combined solution over a period of 48 hours. The linear swelling of shale pellets in the Presence of DI water was maximum while the swelling of shale pallets in the presence of polymer solution, surfactant solution, and polymer-surfactant solution was greatly reduced as compared to the swelling in DI water. The linear swelling of shale pallets in the polymer-surfactant solution (0.4%) - (0.25%) was approximately 107%.\u0000 The associative polymer and Gemini Surfactant have positive pendant groups and long alkyl chains in their structures. The positive pendant groups attach with the clay content in the shale while long alkyl chains encapsulate the shale minimizing the interaction of water with shale. Therefore, the synergistic effect of both polymer and Gemini surfactant improves the shale inhibition characteristics. This combination of associative polymer and Gemini Surfactant would be potential additives for drilling fluids to modify shale swelling and hydration inhibition characteristics.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"17 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527867","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 Case Study Appling Multi-Well Saturation Height Modeling Combined with Pore Geometry Advanced Petrophysical Rock Types for Integrated Reservoir Characterization and Field Development Studies","authors":"G. W. Gunter, M. Y. Sahar","doi":"10.2523/iptc-23773-ms","DOIUrl":"https://doi.org/10.2523/iptc-23773-ms","url":null,"abstract":"\u0000 The objective of this extended abstract is to highlight how integrated studies can be enhanced and reduce uncertainty by applying these new methods including multi-well saturation height functions, advanced petrophysical rock typing methods, advanced core-log integration, machine learning & neural network algorithms. We include a generic reservoir case study showing the improved workflow.\u0000 A major challenge in most studies is how to propagate fluid saturation in a 3D model. Using the new Multi-Well Saturation Height Function method allows for improved cored-log integration of Petrophysical Rock Types (PRT) using Open Hole logs. To tackle this issue, an integrated workflow has been deployed which included the following steps (Gunter et.al. 2018, 2020-2022).\u0000 Lithofacies, pore geometry, pore types, core data and fluid contacts must be understood. Core-log integration to calibrate core and rock properties from deterministic to probalistic methods should be used and results compared. Petrophysical Rock Types definition and validation at the cored wells are extended to the non-core wells using Statistical/Probabilistic methods. A multi-well Saturation Height Modeling (SHM) is implemented based on Petrophysical Rock Types and matching fluid saturations from well logs. This multi-well approach allows a better estimation of Free Water level, improved understanding of reservoir compartmentalization and reduced uncertainty over traditional single well saturation height models.\u0000 The case study shows how this new workflow and application provides an efficient distribution of fluid saturations based on capillary theory, fluid contacts, petrophysical rock types, and pore geometry. Successful 3D models must have an excellent geological representation of the reservoir system including thin section information, mineral composition calibration, pore geometry, capillary properties, and flow capacity of reservoir units. Core log integration must be validated to identify cutoffs and then define petrophysical rock types and permeability equations.\u0000 The above enables, from statistical standpoint, successful selection of the inputs logs that would discriminates between the defined rock types through a Linear Discriminant Analysis, which is a critical point in the performance rock types propagation in the non-cored intervals/ wells.\u0000 Utilization of multi-well saturation height model improves results, the 3D distribution of the fluids and identifies fluid contacts with less uncertainty, than single well based methods.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"21 6","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528378","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}