Geoenergy Science and Engineering最新文献

{"title":"Carbonate rock physics model using different approaches to estimate rock frame stiffness","authors":"Shahram Danaei ,&nbsp;Masoud Maleki ,&nbsp;Denis J. Schiozer ,&nbsp;Alessandra Davolio","doi":"10.1016/j.geoen.2024.213443","DOIUrl":"10.1016/j.geoen.2024.213443","url":null,"abstract":"<div><div>Deepwater carbonate reservoirs in the Brazilian pre-salt have emerged as significant hydrocarbon plays in the region and globally. Seismic monitoring of these reservoirs is crucial to provide information for well placement assessments, to reduce uncertainty in reservoir models, and to enhance model-based decision making. To integrate seismic data quantitatively, a petroelastic model (PEM) is required to estimate elastic properties. The modeling of the rock frame stiffness is an essential part in the study of PEM. However, this becomes more complex for carbonate rocks given their diverse pore-types. One way for estimating stiffness is to model each distinct pore-type and include them into the overall rock frame (different inclusion models). In this research, an alternative approach is explored to estimate the rock frame stiffness. A proxy model is employed, and its coefficients are subsequently calibrated with well-log information. Two PEMs were developed using different approaches for rock frame stiffness modeling. The first was inspired by inclusion models and incorporated two pore types (compliant and stiff pores) for the modeling process. The second considered a mathematical regression model as a proxy to relate reservoir porosity to the rock frame stiffness. These two PEMs were tested on the Brazilian pre-salt carbonate rocks of the Barra Velha (BVE) formation using well-log data from three wells and core sample measurements for one well. The accuracy of the PEMs’ performances was assessed by measures (such as, mean absolute error and root mean square error) and visual comparisons of their predictions. The results showed that both PEMs predicted velocities (compressional and shear) within an acceptable match with the actual well-log data. Similarly, when tested on the core samples, the PEMs produced comparable results, which indicates the validity of the proxy, not only at the well-log scale but at the core scale. The visual comparison and the accuracy analyses of the results for all three wells confirmed that the two PEMs had comparable predictions. This is significant given that the proxy simplifies the modeling process and facilitates the representation of various pore-types in the prediction of elastic properties in carbonate rocks. Overall, the proxy for the rock frame stiffness modeling is a computationally less expensive model compared to the inclusion models which involve modeling of various pore-types. It also offers a straightforward model which enables the quantitative integration of seismic data in a multidisciplinary team of geosciences and petroleum engineers (for instance, early engagement of petroleum engineers in 3D/4D seismic history matching).</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213443"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142660027","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":"Real-time estimation of geomechanical characteristics using drilling parameter data and LWD","authors":"Ye Liu ,&nbsp;Shuming Liu ,&nbsp;Jiafeng Zhang ,&nbsp;Jie Cao","doi":"10.1016/j.geoen.2024.213450","DOIUrl":"10.1016/j.geoen.2024.213450","url":null,"abstract":"<div><div>In the pursuit of real-time estimation of geomechanical characteristics, this study integrates surface drilling telemetry with Logging While Drilling (LWD) to predict shear wave velocity (<em>Vs</em>) and other essential elastic properties of rock formations. Real-time prediction of these parameters is crucial for enhancing wellbore stability, fracture propagation, and geosteering operations, thereby improving both safety and operational efficiency. Traditional methods, which rely solely on conventional well-logging data, often fail to incorporate the dynamic information embedded within drilling mechanics, limiting their applicability in real-time decision-making.</div><div>Empirical validation using real drilling data from the Volve oil field demonstrated the enhanced performance of our self-attention-based Transformer model through the integration of drilling engineering parameters. In the initial testing, the model significantly improved the accuracy of predicting <em>Vs</em>, increasing it from 92% to 97.2%, alongside notable improvements in elastic property predictions. Specifically, the mean absolute error (MAE) for shear modulus decreased from 0.186 to 0.059, and bulk modulus from 0.189 to 0.040. Additionally, cross-validation using well F11A further confirmed the model's robustness, with the MAE for shear modulus decreasing from 0.134 to 0.053 upon incorporating drilling data. Compared to traditional LSTM-based models, the Transformer exhibited superior capability in extracting temporal features, validating its effectiveness in real-time elastic property prediction. These results underscore the model's capacity to enhance real-time decision-making in drilling operations.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213450"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573165","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":"Modeling interactions between hydraulic fracture and pre-existing microcracks in crystalline rocks using hydro-grain-texture model","authors":"Suifeng Wang ,&nbsp;Yanhui Han ,&nbsp;Wanrui Hu ,&nbsp;Xianyu Zhao ,&nbsp;Liping Zhang ,&nbsp;Tao Wang","doi":"10.1016/j.geoen.2024.213459","DOIUrl":"10.1016/j.geoen.2024.213459","url":null,"abstract":"<div><div>The heterogeneity of the mineral grains and pre-existing microcracks significantly impacts the cracking behavior of crystalline rocks. However, these characteristics have not been adequately addressed in the existing hydraulic fracturing studies. To bridge this gap, this study introduces a fluid-solid coupling method enhanced by a microcrack simulation component, called Hydro-Grain-Texture Model (HGTM), to investigate the influence of mineral structures and pre-existing microcracks on hydraulic fracturing processes in granite. Compared with existing methods, the HGTM incorporates a “grain growth” algorithm that can more accurately represent the characteristics of mineral grains. This study investigates the base case of intact rock, and four additional cases featuring microcracks oriented in various directions, i.e., horizontal, diagonal, vertical and complex microcracks, under both hydrostatic and non-hydrostatic in-situ stress conditions. The HGTM effectively captures a range of microscopic behaviors during the hydraulic fracturing of granite, including the formation of rock fragments, fracture branches, and dry fractures, among others. Furthermore, by comparing numerical results for breakdown pressure with analytical results, the accuracy of the HGTM in predicting breakdown pressure is substantiated. The findings indicate that mineral structures (grain boundaries) and microcracks contribute to a more intricate pattern of hydraulic fractures propagation. The pre-existing microcracks significantly influence the propagation path of primary hydraulic fractures. Under fluid-driven pressures, these pre-existing microcracks experience shear failure distinct from tensile failure observed in the surrounding rock matrix.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213459"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573166","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":"Multi-element drilling parameter optimization based on drillstring dynamics and ROP model","authors":"Weiguo Hai ,&nbsp;Yingming He ,&nbsp;Yafeng Li ,&nbsp;Yonggang Shan ,&nbsp;Chong Wang ,&nbsp;Qilong Xue","doi":"10.1016/j.geoen.2024.213460","DOIUrl":"10.1016/j.geoen.2024.213460","url":null,"abstract":"<div><div>Drilling parameter optimization is a crucial methodology for enhancing the rate of penetration (ROP) and serves as an essential strategy for achieving cost reduction and efficiency improvements in drilling engineering. Drilling parameters optimization can be conducted based on the drillstring dynamics model and ROP model. Still, there remains a notable gap in multi-element drilling parameter optimization studies considering both models concurrently. This paper addresses the challenges associated with increasing ROP within the M formation of the D oilfield located in the Middle East. Establishing a comprehensive full-scale drillstring dynamics model alongside an ROP prediction and optimization model based on artificial neural networks(ANN). By taking into account energy transfer efficiency, vibration intensity, and various factors influencing ROP during the drilling process, we propose an innovative workflow for multi-element drilling parameter optimization. Ultimately, this process facilitates parameter optimization for well P, followed by application tracking. The results indicate that after employing the recommended combination of parameters, well P achieves an average ROP of 10.16 m/h representing a 51.4% increase compared to previously completed wells thus fulfilling our objective of enhanced ROP. Furthermore, the implementation of this parameter optimization substantiates both its effectiveness and reliability as a method for multi-element drilling parameter optimization. It offers recommendations for optimal controllable drilling parameters tailored to specific target blocks and formations while providing corresponding design guidance during the initial stages of drilling planning.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213460"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573058","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 4IR-Driven operational risk model for CO2 storage in deepwater abandoned hydrocarbon reservoirs","authors":"Md Shaheen Shah ,&nbsp;Faisal Khan ,&nbsp;Sohrab Zendehboudi ,&nbsp;Abbas Mamudu ,&nbsp;Dru Heagle","doi":"10.1016/j.geoen.2024.213425","DOIUrl":"10.1016/j.geoen.2024.213425","url":null,"abstract":"<div><div>This study presents the development of an advanced operational risk model that leverages Fourth Industrial Revolution (4IR) technologies to optimize carbon dioxide (CO₂) storage within deepwater abandoned hydrocarbon reservoirs. The model systematically combines Artificial Neural Networks (ANN) with the optimization capabilities of Genetic Algorithms (GA) and the probabilistic analysis strengths of a Bayesian Network (BN) to perform dynamic and comprehensive risk assessments. By applying the model to a dataset covering a 200-year timeframe, it effectively forecasts CO₂ storage capacities while simultaneously evaluating associated risks across different operational scenarios. One of the key innovations of this model is the introduction of a novel loss function designed to precisely manage forecast deviations and enhance the efficiency of operational processes. This function is critical in ensuring that the model remains robust and accurate in real-time risk assessments, allowing for more reliable decision-making in CO₂ storage operations. In addition, the study conducts an economic evaluation that underscores the crucial role of 45Q tax credits in bolstering the financial sustainability of carbon sequestration projects. The analysis highlights how these credits significantly reduce the economic barriers to adopting carbon utilization, storage, and sequestration (CUSS) technologies, making large-scale implementation more feasible. The model's performance is underscored by its ability to achieve a 49% CO₂ retention rate over two centuries, with an impressively low average error margin of 0.249%. These results highlight the model's impressive efficiency and accuracy, while also demonstrating its capacity to markedly improve the predictability of CO₂ storage outcomes. The findings suggest that this model could play a pivotal role in advancing global sustainability efforts by optimizing CO₂ storage processes, thereby contributing to the reduction of atmospheric CO₂ levels and supporting long-term climate goals.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213425"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573063","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":"Non-isothermal simulation of wormhole propagation in fractured carbonate rocks based on 3D-EDFM","authors":"Weiren Mo ,&nbsp;Youshi Jiang ,&nbsp;Yongming Li ,&nbsp;Tai Chang ,&nbsp;Kun Liu","doi":"10.1016/j.geoen.2024.213453","DOIUrl":"10.1016/j.geoen.2024.213453","url":null,"abstract":"<div><div>The current models of fractured carbonate acidizing are limited to 2D simulation or are solely applicable to the acidizing process in porous media with few fractures, neglecting the acid flow between intersecting fractures. In response to these issues, a coupled 3D thermal-hydro-chemical 3D-EDFM method is developed to simulate the acidizing process in fractured carbonate rock. The fractured carbonate acidizing model is coupled by 3D-EDFM, the two-scale continuum model and the heat transfer model in this paper. Numerical simulations of acidizing under different temperatures are performed, and the simulation results are consistent with previous experimental findings, thus verifying the accuracy of the model. Through simulations, we found that as the flow rate increases, the fracture plane transitions from acting as a “dissolution object of acid” to serving as a “transport channel of acid”. The density and inclination angle of the fracture plane significantly affect the wormholes propagation. The presence of fracture planes accelerates the pressure drop during acidizing and complicates the distribution of the acid-rock reaction heat. Unlike in the 2D model, we observe that when cold acid is injected into high-temperature fractured carbonate rock, the acid cools the rock from the inside out. Although higher rock temperatures lead to an increase in <span><math><mrow><msub><mrow><mi>P</mi><mi>V</mi></mrow><mrow><mi>B</mi><mi>T</mi></mrow></msub></mrow></math></span>, the difference in the optimum injection rate remains minimal. Compared to porous media without fracture planes, the fracture plane increases the optimum injection rate, and appropriately increasing the injection rate can more effectively utilize the transport characteristics of natural fractures.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213453"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142659833","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":"Numerical simulation of gravel packing in multi-branch horizontal wells in hydrate reservoirs based on CFD-DEM coupling","authors":"Tiankui Guo ,&nbsp;Wenyu Wang ,&nbsp;Xin Yang ,&nbsp;Ming Chen ,&nbsp;Hongzhi Xu ,&nbsp;Liyong Guan ,&nbsp;Mingkun Lv","doi":"10.1016/j.geoen.2024.213445","DOIUrl":"10.1016/j.geoen.2024.213445","url":null,"abstract":"<div><div>The current single-wellbore gravel packing completion method for hydrate production is limited by its narrow pressure reduction range, leading to reduced production capacity in later stages. To address this, the \"branch horizontal well completion with full-wellbore gravel packing and sand control\" method has been proposed to significantly expand the pressure reduction range and enhance natural gas production. However, there is a lack of comprehensive studies on gravel packing in branch horizontal wells, the construction design for gravel packing and sand control in branch horizontal wells lacks a solid theoretical foundation. In this study, we establish a CFD-DEM coupled model to simulate gravel packing in single and multi-branch horizontal wellbores, accurately capturing particle movement. We investigate the effects of injection rate, gravel concentration, branch wellbore length, and branch wellbore angle on gravel packing efficiency. The five distinct stages of gravel packing in branch horizontal wells are elucidated. Results indicate that increasing the fluid injection rate, reducing sand concentration, and decreasing both the length and angle of the branch wellbore can significantly improve the packing efficiency. Notably, the filling ratio in the branch wellbore at an angle of 15° was 11.42% higher than that at 30°; As the length of the branch wellbore increases from 1m to 2m, the filling ratio of the branch wellbore decreases significantly. We recommend utilizing a high injection rate (0.6 m³/min), low gravel concentration (3%) to optimize the filling ratio and compaction in both the main and branch wellbores.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213445"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142586210","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":"Thermosensitive polymer/nanosilica hybrid as a multifunctional additive in water-based drilling fluid: Rheologicalproperties and lubrication performance as well as filtration loss reduction capacity","authors":"Liping Cheng ,&nbsp;Xue Wang ,&nbsp;Guangbin Yang ,&nbsp;Shengmao Zhang ,&nbsp;Yujuan Zhang ,&nbsp;Lu Sun ,&nbsp;Xiaohong Li ,&nbsp;Laigui Yu ,&nbsp;Pingyu Zhang","doi":"10.1016/j.geoen.2024.213455","DOIUrl":"10.1016/j.geoen.2024.213455","url":null,"abstract":"<div><div>In previous studies, for obtaining a flat rheological drilling fluid, binary and ternary thermosensitive silica (SiO₂) nanohybrids as rheological modifiers were synthesized using N-isopropylacrylamide with a thermal association temperatureof 32–33 °C as the thermosensitive monomer [J. Petrol. Sci. Eng. 219 (2022), 111096; Geoenergy Science and Engineering 228 (2023), 211934]. However, the as-synthesized SiO₂ nanohybrids exhibited limited performance and low thermal transition temperature. Thus surface initiated atom transfer radical polymerization was utilized to graft hydrophilic poly(ethylene glycol) methyl ether methacrylate (PEGMA) onto SiO₂ surface to obtain PEGMA/SiO₂ nanohybrids with an elevated thermal association temperature of 75 °C. The morphology and structure of the as-synthesized PEGMA/SiO₂nanohybrid were characterized by infrared spectroscopy and transmission electron microscopy; and its effects as a thermosensitive multifunctional additive on the rheological properties and lubrication performance as well as filtration loss reduction capacity of a water-based drilling fluid were investigated. Results indicate that the drilling fluids with 1.0% PEGMA/SiO₂ nanohybrids exhibited obvious thermal thickening behavior in the temperature range of 70–80 °C; at low temperatures, however, they had a significant viscosity reduction effect therein. At room temperature, the apparent viscosity and plastic viscosity were reduced by 68% and 50%, respectively. Besides, due to the tightly packed plugging layer formed by PEGMA/SiO₂ nanohybrids and bentonite, the filtration loss of the drilling fluids containing 1.0% PEGMA/SiO₂ nanohybrid was reduced by 37% as compared with that of the base slurry; and the lubrication coefficient was decreased by up to 50%. Moreover, the high-temperature aging process promoted the intermolecular interactions of the nanohybrids and their interaction with bentonite flakes, thereby further improving the rheological behavior, filtration reduction ability, and lubricity of the drilling fluids. The as-synthesized thermosensitive PEGMA/SiO₂ nanohybrids with excellent multifunctionality could find promising application in water-based drilling fluids.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213455"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142539425","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 experimental investigations on salt precipitation during CO2 geological storage","authors":"Xiaolong Sun ,&nbsp;Keyu Liu ,&nbsp;Senyou An ,&nbsp;Helge Hellevang ,&nbsp;Yingchang Cao ,&nbsp;Juan Alcalde ,&nbsp;Anna Travé ,&nbsp;Guanghui Yuan ,&nbsp;Chenguang Deng ,&nbsp;Enrique Gomez-Rivas","doi":"10.1016/j.geoen.2024.213451","DOIUrl":"10.1016/j.geoen.2024.213451","url":null,"abstract":"<div><div>Salt precipitation due to formation drying is a critical secondary alteration process that significantly impairs reservoir injectivity in the context of CO₂ geological storage. In this work, salt precipitation during CO₂ injection is reviewed primarily through various experimental studies. First, the experimental systems for salt precipitation studies, namely core-flooding, microfluidic-chip, static batch, and surface drying experimental systems, have been described to present their respective experimental procedures and merits, as well as corresponding applications. Subsequently, following the general description of the formation mechanisms of salt precipitation, the macro and micro salt distribution patterns at the reservoir and pore scales have been summarized. Finally, and most importantly, this study provides a comprehensive analysis of the controlling factors for salt precipitation, categorized into four different groups, according to the brine, rock, gas, and injection scenario aspects. Among all these factors, brine salinity, CO₂ injection rate and initial reservoir properties are considered the most critical in determining the amount and distribution of precipitated salts and the degree of injectivity impairment. The effects of multi-scale reservoir heterogeneity and rock wettability on salt precipitation are attracting growing consideration, while the brine and gas composition studies are receiving less attention due to their relatively minor influences on reservoir alteration. Due to the limited specimen sizes, the ex-situ brine replenishment may be underestimated in core-flooding and microfluidic-chip experiments. This may result in a potentially significant underestimation of the volume of local salts and the potentially inaccurate prediction of the drying process during CO₂ injection in many such experiments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213451"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573056","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":"Gas kick dynamic circulation in MPD operations with water based drilling fluid: Maximum casing pressure modeling and validation","authors":"Márcia Peixoto Vega ,&nbsp;Lindoval Domiciano Fernandes ,&nbsp;Gabrielle Fontella de Moraes Oliveira ,&nbsp;Filipe Arantes Furtado ,&nbsp;Claudia Míriam Scheid ,&nbsp;Eduardo da Cunha Hora Paraíso ,&nbsp;Umberto Sansoni Jr. ,&nbsp;Alex Waldmann ,&nbsp;André Leibsohn Martins ,&nbsp;Antonio Carlos Vieira Martins Lage","doi":"10.1016/j.geoen.2024.213437","DOIUrl":"10.1016/j.geoen.2024.213437","url":null,"abstract":"<div><div>The use of water-based drilling fluids enables the rapid detection of a gas influx by pit gain monitoring due to the low solubility of gases in the aqueous medium. Moreover, as the influx remains as a free gas, it undergoes a process of expansion the further it rises through the well, changing the pressure profiles and producing a pressure peak when it reaches the surface. Therefore, the gas influx must be controlled appropriately. Otherwise, the maximum pressure experienced during the kick circulation may exceed the safety limits of surface equipment, placing the operation and the rig crew in a hazardous situation. The Managed Pressure Drilling (MPD) technique allows for a more precise detection and control of the influx while retaining the ability to circulate dynamically small volumes of gas kick through the riser, minimizing the risks involved and the non-productive time (NPT). However, the decision of when to apply dynamic or conventional circulation techniques must be considered carefully, taking into account factors such as predictions of pressure peaks, as well as intensity and volume of the kick. In this way, it is paramount that the maximum pressure during the circulation be estimated before the operation begins to ensure that the decision is made correctly. This paper presents the results of a gas kick circulation simulator specifically developed to predict pressure peaks. This simulator uses a mathematical model based on algebraic equations whose solution requires low computational effort and, therefore, regarding gas kick incidents, is an interesting tool that can aid in guiding decision-making. The results of pressure peaks were successfully validated by employing literature data, experimental drilling setup runs and simulations performed in a commercial software largely consolidated in the petroleum industry: Drillbench.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213437"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142552238","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}