Day 3 Wed, February 14, 2024最新文献

{"title":"Comprehensive Energy Exergy Economic and Environmental Assessment of an Integrated Organic Rankine Cycle Solid Oxide Fuel Cell and Absorption Chiller System Fueled by Steam Reformed Natural Gas","authors":"R. Sornumpol, P. P. Nimmanterdwong","doi":"10.2523/iptc-24616-ms","DOIUrl":"https://doi.org/10.2523/iptc-24616-ms","url":null,"abstract":"\u0000 This research presents a thorough evaluation of an integrated system comprising a Solid Oxide Fuel Cell (SOFC), Organic Rankine Cycle (ORC), and Absorption Chiller (AC). The study employs ASPEN PLUS V10 to assess the system's energy, exergy, economic, and environmental performance. The Integrated SOFC-ORC-AC system offers trigeneration capabilities, generating electricity, cooling, and heating from a single fuel source. It demonstrates potential as an efficient and environmentally friendly energy generation method. The system can be fuelled by steam-reformed natural gas or renewable fuels like biogas or syngas. The SOFC, employing a solid electrolyte, facilitates an electrochemical reaction with hydrogen, producing electricity and heat. The exhaust gas further powers the ORC and AC units. The study builds a mathematical model, assuming steady-state, isothermal, and chemically equilibrated conditions. The SOFC and ORC simulations utilize the Peng Robinson model, while the LiBr absorption chiller employs the ELECNRTL property method for fluid thermodynamic properties. The SOFC electrical model was validated against real-world data, ensuring accuracy. The study also tested a single-effect LiBr absorption chiller, comparing results with experimental data. The operating pressure's effect on SOFC performance was evaluated, demonstrating reduced voltage losses and increased cell voltage and power density at higher pressures. Operating temperature elevation enhanced electrochemical reactions, resulting in higher cell voltage and power density, despite increased voltage losses. Augmenting the fuel utilization factor reduced voltage losses, leading to increased cell voltage and power density. The SOFC-ORC system efficiency peaked at 58.9% at the highest operating pressure, influenced by factors like compressor consumption and high fuel flow rate. Redirecting exhaust gas for waste heat recovery produced hot water, influencing the Coefficient of Performance (COP) of the LiBr absorption chiller. Mass flow rate had a smaller impact compared to hot water temperature. Exergy analysis revealed the SOFC's high efficiency (83.92%), while the steam turbine and LiBr absorption chiller demonstrated lower exergy efficiencies (70% and 32.6% respectively). Cost analysis indicated that the SOFC power plant was the most significant investment at 130,715 $, highlighting the long-term benefits of the integrated system in terms of high efficiency, low emissions, and fuel flexibility. This research offers a comprehensive assessment of the integrated SOFC-ORC-AC system, shedding light on its potential as an efficient and environmentally friendly energy generation solution. The study's findings contribute to the advancement of sustainable energy technologies, emphasizing the importance of trigeneration systems for future energy landscapes.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528371","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":"Application of Stochastic Petroleum Economics for Unconventional Resources: Estimating the Gas Break-Even Price for a Liquids Rich Unconventional Development","authors":"Michael Macphee, Shamsul Anuar, Abdulbari Alhayaf","doi":"10.2523/iptc-23179-ms","DOIUrl":"https://doi.org/10.2523/iptc-23179-ms","url":null,"abstract":"\u0000 To assess the economic viability of a liquids rich unconventional gas project, a break-even sales gas price (BEP) is determined. The calculated BEP for such projects is uncertain as market pricing and revenue from secondary liquid production is uncertain. This secondary revenue provides a partial yet significant offset to capital and operating costs. Through the application of stochastic methods, uncertainty associated with the required project sales gas BEP can be calculated to inform management decision making.\u0000 Stochastic economic evaluation of a generic unconventional gas development was undertaken using synthetic data. Fluid windows range from lean (dry) gas to liquid-rich with multiple uncertain secondary product revenue streams from these fluid windows impacting heavily on the resulting sales gas BEP. Further impacting the sales gas BEP are other uncertain inputs including: capital costs, operating costs, production, and project timing. Probability distributions were assigned to forecast secondary product prices, capital and operating costs. Through the application of this model combined with a novel approach to calculating the BEP (after-tax), uncertainty associated with the resulting BEP can be calculated.\u0000 The model delivered clear visibility on BEP uncertainty. Key statistics include the mean, median, percentiles, and probability of the project BEP exceeding defined price thresholds.\u0000 The primary purpose of completing a stochastic economic evaluation for capital intensive oil and gas projects is to understand uncertainty associated with the expected project NPV to enable a project FID decision. In jurisdictions with a regulated natural gas market, selected gas projects receive a fixed long-term gas price with infrequent ability to renegotiate the gas price. The fixed gas price is established by the regulator with intent to provide the producer with a fixed rate of return. However, for liquids rich gas projects, the project return is never truly fixed given significant exposure to market pricing for these secondary products, amongst other factors. Hence it is essential to understand the probabilistic nature of the BEP.\u0000 Given significant capital requirements for necessary upstream and midstream infrastructure, once an investment decision has been made, a continuous drilling campaign must be sustained to ensure full use of this fixed infrastructure. Once the primary build-out of this infrastructure is complete and given relatively certain drilling and rigless costs, the primary uncertainty becomes pricing and revenues from secondary products.\u0000 This model supports decision making by providing visibility on the expected BEP and probable range of the BEP. The model results also established a clear relationship between gas BEP and pricing for secondary products.\u0000 In contrast to traditional stochastic economic analysis focused on project NPV, the focus of this analysis is on the implied after-tax BEP. Given thousands of iterations are requi","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"35 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528351","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":"Performance Improvement Through Continuous Learning – A Case Study of World's First Unified 30 and 20 Casing While Drilling Project","authors":"A. Soi, S. Prakash, R. Sharma, M. Zayyan, S. Narayanan, D. Herrera Gomez, J. P. Halma, A. V. Balen","doi":"10.2523/iptc-24438-ms","DOIUrl":"https://doi.org/10.2523/iptc-24438-ms","url":null,"abstract":"The objective of this paper is to present the valuable lessons learned in the world's first unified 30\" and 20\" non-directional Casing While Drilling (CWD) project in ONGC's Bombay High field and how the operational workflow was optimized based on those learnings to further enhance operational efficiency. The focus is on addressing the challenges encountered during the operation and sharing the corresponding solutions.\u0000 The project involved drilling six wells using CWD technology in the exploratory fields of Bombay High. Specially designed Copper-Bronze Drillable Alloy Bits (DABs) were attached to the bottom of the casing to drill and case the 30\" conductor pipe and the 20\" surface casing. A casing drive system provided mechanical and hydraulic energy to the assembly and DABs. Based on challenges faced and experiences gained in the six well pilot project, the operational procedures and workflow were constantly optimized to ensure continuous improvement in well delivery timelines.\u0000 The implementation of CWD technology reduced the average drilling time of the 30\" and 20\" sections from an average of 12.83 days to 5.95 days, resulting in significant savings of 41 offshore rig days in the six-well pilot project. The use of CWD technology eliminated the need for piling the 30\" conductor casing, 17.5\" pilot hole drilling, and subsequent hole enlargement to 26\" to facilitate lowering of 20\" casing. This improvement in the drilling efficiency allowed ONGC to meet their drilling targets, reduce NPT, and improve well delivery rate. The CWD technique also reduced the HSE exposure of the rig crew, as the risks associated with piling, higher man hours, tripping operations and manual handling of large sized casings were eliminated. The paper explains the various optimizations that were done in the process of CWD to overcome unique challenges that helped improve the well delivery timeline from average 6.25 days in the first 3 wells to average 5.65 days in the last 3 wells.\u0000 This paper provides a comprehensive case study of the world's first unified 30\" and 20\" CWD project in the Bombay High field. The lessons learned from addressing extremely unique challenges such as high torque, casing sinking, DAB drill-out issue, and CRT stuck issues during the operation are shared in the paper. The insights gained from this study will benefit drilling engineers, well planners, and operators seeking to implement CWD technology more efficiently, reduce NPT, optimize well delivery, and maintain safety standards.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"486 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528187","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":"Cased-Hole Anisotropy Mechanical Properties and Stress Evaluation Using Through-the-Bit Dipole Sonic for Fracturing Optimization in Horizontal Deep Gas Well, North Oman","authors":"Mohamed Abdel Azim, S. Kurniadi, Adam Donald, Pascal Millot, Sumaiya Ali Al Bimani, S. al Farsi, Anam Al Bulushi, B. Mowad","doi":"10.2523/iptc-23539-ms","DOIUrl":"https://doi.org/10.2523/iptc-23539-ms","url":null,"abstract":"\u0000 SR gas field is located the North Oman Salt Basin. The BK and MQ are the two main formations targeted for gas production. In most cases, these formations are clastic deep tight gas reservoirs that contain considerable hydrocarbon reserves but exhibit ultralow permeability. The poor connectivity between the pores may significantly reduce the recovery for economic gas production. The formations were initially developed with fractured vertical wells targeting up to 10 different hydrocarbon units. A similar approach was carried forward in highly deviated to horizontal wells targeting the tighter zones. However, the intrinsic geomechanical, petrophysical, and lithological heterogeneities of these tight units impact not only the fracture geometry and conductivity distribution but also the drainage efficiency of the fractured zones. This phenomenon manifests as variations in the units, thereby influencing their contributions to the commingled production, with the areas of higher mobility dominating the total gas production in the current well architectures.\u0000 A horizontal well designed to obtain the production from the tight zone experienced some challenges on the drilling and completion. To address the operational challenges drilling, logging, and completing horizontal wells in this field, the acquisition of cased-hole logging data to characterize the mechanical anisotropy with a through-the-bit sonic dipole sonic tool deployed via a tractor has emerged as a compelling logging solution. The logging-while-drilling sonic tool has limitations in measuring shear anisotropy, and using the sonic through-the-bit tool in open hole poses for getting stuck. In this case study, sonic data were recorded through casing with the latest-generation slim dipole sonic tool via e-coil across the horizontal section, the first in the world for this type of deployment. The dipole shear sonic tool is capable of recording shear anisotropy, which is used to determine key elastic properties to assess the hydraulic requirements for optimizing the efficiency of fracturing BK units across the horizontal section.\u0000 We present fundamental considerations for acquiring and evaluating rock mechanical formation anisotropy using through-the-bit dipole shear sonic tool inside tubing by an e-coil. This work uses methods to assess the dynamic variations of in-situ stress by using shear anisotropy and to determine the key elastic properties to identify the hydraulic requirements for fracturing individual units or a combination of them along the horizontal section. Included in the study are considerations of logging requirements, conveyance method, and sonic data processing and results as well as petrophysical evaluation and other reservoir criteria.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"106 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527915","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":"Using Data-Driven Analytics Workflow to Find out Highly Watered-Out Mechanism and Novel Solution in Horizontal Wells for Heterogeneous Carbonate Reservoir","authors":"Dandan Hu, Wenhuan Li, Qianyao Li, Yihang Chen, Yuanbing Wu, Songhao Hu","doi":"10.2523/iptc-23242-ms","DOIUrl":"https://doi.org/10.2523/iptc-23242-ms","url":null,"abstract":"\u0000 K reservoir is a highly heterogeneous pore carbonate reservoir with thin layer and high permeability zone at the top. It adopted the overall horizontal well pattern, the water cut rose rapidly and \"double-inverse\" water flow dominant channel formed subsequently after water injection. The water cut of most producers rose rapidly to more than 85%, resulting in a large decline of oil production and poor sweep efficiency.\u0000 In the paper, a novel methodology and data-driven analytics workflow was established for detecting the characteristics of watered-out horizontal wells, revealing the highly watered-out mechanism, describing the residual oil mode on different main factors and proposing the solution for highly watered-out horizontal wells. The paper analyzed the rules and characteristics of water cut change after water injection and clarified the effect of the matching relationship of horizontal well trajectory and the main factors on the rapid rise of water cut. To diagnose the mechanism and reasons for the rapid rise of water cut, the watered-out conditions have been described for producers, injectors and inter-wells in longitudinal direction at different times through passing wells from lower formation based on logging data. The paper put forward the theoretical calculation formula for liquid effusion of horizontal well bore and the prediction formula of liquid discharge time. By discharging the accumulated liquid from the well trajectory at the high permeability zone, the residual oil with the well trajectory in other layers could be used to expand flooding volume, reduce the water cut of the producer, and restore the normal production for these high water cut wells. It was indicated that the actual incremental oil result for these wells were decided by the relationship of well trajectory and the main controlling factors and the remaining oil distribution.\u0000 This workflow has successfully been applied to a giant heterogeneous carbonate reservoir. The water cut of most wells was significantly reduced, with an efficiency of more than 90.0%. The time of liquid discharging and water cut controlling was 1 and a half months to 4 months, and the water cut decreased between 8% and 24%, and the total incremental oil of 2 million barrels has been achieved.\u0000 Strong heterogeneity in carbonate reservoirs of Middle East generally develops and easily causes high water cut for producers, the innovative strategies in the paper has good adaptability and reference for these reservoirs.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"18 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528012","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 Quantitative Approach to Characterizing Natural Fractures in Tight Gas Sands, Using Data from Mud Loss","authors":"X. Tan, H. Li, L. Wen, H. Liu, T. Liu, C. Jia, S. Wang, R. Zheng, J. Liu","doi":"10.2523/iptc-23560-ms","DOIUrl":"https://doi.org/10.2523/iptc-23560-ms","url":null,"abstract":"\u0000 Natural fractures have a significant impact on the development of tight sandstone gas reservoirs. However, over the years, limited types of data have been used in characterizing fractures, leading to generally unsatisfactory prediction accuracy. This paper presents a quantitative prediction approach using data from mud loss during drilling, taking the J Gas Field in the Ordos Basin, China, as a case study. The target zone is the H1 member of the Upper Paleozoic, considered a set of superimposed braided-river sand bodies. In this geological setting, horizontal wells have been the preferred choice for exploiting Zone H1. The approach comprises the following steps: First, fracture development characteristics were obtained by studying core samples, image logs, lithology, bed thickness, and seismic attributes. Second, the importance of data from mud loss on fracture prediction was discussed, and the relationship between fractures and faults was analyzed. Third, log responses after core calibration were collected at mud loss points, and potential fractures were identified through well logging. Finally, a 3D model of fracture intensity was created to provide a quantitative characterization of fracture distribution, and the prediction accuracy was verified. The key findings are as follows: (1) Mud loss data can help in locating subsurface clusters of fractures, as mud loss is inherently linked to fracture dimensions. Therefore, mud loss can serve as a valuable index for describing fractures. (2) Major faults play a crucial role in controlling the distribution of fractures, with the orientation of faults also influencing this distribution. For instance, East-West faults have a more pronounced impact. (3) The occurrence of mud loss has a dual nature. On one hand, moderate mud loss can be an indicator of promising gas production. On the other hand, uncontrolled mud loss can result in severe formation damage and unexpected drilling termination. (4) The constructed fracture intensity model offers a quantitative prediction of fracture distribution, and the result demonstrates a satisfactory prediction accuracy. What sets this paper apart is the introduction of a quantitative methodology for predicting natural fractures, making full use of often neglected mud loss data.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"242 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528039","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":"Generative Artificial Intelligence for Geomodeling","authors":"S. Misra, Jungang Chen, Polina Churilova, Y. Falola","doi":"10.2523/iptc-23477-ms","DOIUrl":"https://doi.org/10.2523/iptc-23477-ms","url":null,"abstract":"\u0000 Subsurface earth models, also known as geomodels, are essential for characterizing and developing complex subsurface systems. Traditional geomodel generation methods, such as multiple-point statistics, can be time-consuming and computationally expensive. Generative Artificial Intelligence (AI) offers a promising alternative, with the potential to generate high-quality geomodels more quickly and efficiently. This paper proposes a deep-learning-based generative AI for geomodeling that comprises two deep learning models: a hierarchical vector-quantized variational autoencoder (VQ-VAE-2) and a PixelSNAIL autoregressive model. The VQ-VAE-2 learns to massively compress geomodels into a low-dimensional, discrete latent representation. The PixelSNAIL then learns the prior distribution of the latent codes. To generate a geomodel, the PixelSNAIL samples from the prior distribution of latent codes and the decoder of the VQ-VAE-2 converts the sampled latent code to a newly constructed geomodel. The PixelSNAIL can be used for unconditional or conditional geomodel generation. In unconditional generation, the generative workflow generates an ensemble of geomodels without any constraint. In conditional geomodel generation, the generative workflow generates an ensemble of geomodels similar to a user-defined source geomodel. This facilitates the control and manipulation of the generated geomodels. To improve the generation of fluvial channels in the geomodels, we use perceptual loss instead of the traditional mean absolute error loss in the VQ-VAE-2 model. At a specific compression ratio, the proposed Generative AI method generates multi-attribute geomodels of higher quality than single-attribute geomodels.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"226 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527906","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":"Machine Learning Application for Hydraulic Fracturing Optimization in a China Tight Gas Field","authors":"Tianjun Yu, Ming Li, Taiji Wang, Kevin Mullen, Jie Zhang, Beryl Audrey, Hai Hua Yang, Gayatri P. Kartoatmodjo","doi":"10.2523/iptc-23274-ms","DOIUrl":"https://doi.org/10.2523/iptc-23274-ms","url":null,"abstract":"\u0000 The normal approach to fracturing optimization in any tight formation involves comparing the production from multiple wells after one or two controlled changes to the design parameters. This approach might not adequately consider the importance of each factor nor disclose hidden relationships between them. The new approach presented in this paper involves applying machine learning to optimize fracturing designs by understanding factors affecting production and by predicting production using a data set of historic wells’ geological, fracturing and production parameters.\u0000 This approach proposed here, when applied to our development asset, increased the prior frac optimization parameters by multiple factors, including geological properties, fracturing parameters, and production data, which will also be applied to predict gas production. The data from 110 wells containing Shan2 and Benxi reservoirs were prepared, trained, and analyzed. Then, 14 trial algorithms were ranked by R2 scores and the best one was used to perform a sensitivity analysis between the factors and production. This result can be used to optimize design parameters and achieve the most economic design.\u0000 Randomly chosen training and testing data sets were used to compare algorithms. Based on R2 scores, a gradient-boosted tree algorithm applicable for both reservoirs was determined to be the best. This algorithm showed that effective thickness and pumping rate have had the greatest impact to gas production from the Shan2 reservoir production, but gas saturation and proppant concentration are the most important for wells producing from the Benxi reservoir. These factors then become the main adjustable parameters in the fracturing design.\u0000 These results were then applied to guide hydraulic fracturing designs of six new wells. The final designs were based on optimizing both production and operating costs. Well testing showed that optimized designs achieved an overall 27% increase in absolute open flow compared with standard designs. Optimized designs incur marginally higher costs, this is offset by a 33% increase in 2 years of cumulative production, which represents an overall economic improvement in this development scenario.\u0000 This principal benefit of the machine learning approach is to create a robust decision making for adjusting hydraulic fracturing designs based on production and economics. In addition, prediction accuracy improves over time with the addition of new wells and longer production history. Finally, this novel approach is proven to maximize gas well productivity and to optimize materials and logistics.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"184 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527908","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":"The Influence of Various Parameters on Petroleum Oil Removal from Produced Water with Novel Nanobubbles/microbubbles Flotation","authors":"M. Colic","doi":"10.2523/iptc-24290-ms","DOIUrl":"https://doi.org/10.2523/iptc-24290-ms","url":null,"abstract":"\u0000 Produced water at offshore and onshore petroleum and natural gas extraction sites is very complex and contains many inorganic and organic contaminants. Such contaminants include free and emulsified petroleum oils and suspended solids. Gas flotation technologies are commonly used to remove finely dispersed oil droplets and suspended solids. New generation of flotation systems use nanobubbles-microbubbles generators that can produce very small bubbles ranging from 1 - 1,000 nanometers and 1-30 microns. However, influence of various parameters such as pH, salinity, temperature, pressure, type, and dosage of polymeric flocculants, mixing energy and hydraulic residence time have not been studied. In this manuscript we present detailed analysis and literature review of parameters that influence the performance of such flotation systems. High molecular weight and high charge density cationic flocculants significantly enhance the removal of dispersed oils and solids. Dual cationic-anionic flocculant approach is particularly efficient. Centrifugal hydrocylone based flotation systems where nucleation of bubbles and flocs occur at the same time are particularly effective. Higher temperature and pH enabled better emulsion flocculation and flotation. Salinity impairs flocculant activation and the performance of flotation system.\u0000 Nanobubbles enhance flotation and flocculation at high NaCl concentrations. We propose a \"hungry black hole\" model for nanobubbles effects in flocculation and flotation: nanobubbles occasionally collapse and like black holes release a strong jet of gas that can then penetrate oil droplets, flocculant chain networks and floc pores. Secondary nano and microbubbles nucleation in those pores then creates large light flocs that float in seconds to the top of flotation units.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"253 19","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527902","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":"High-Resolution Characterization of Carbonate Source Reservoir Heterogeneity for Enhanced Production Optimization","authors":"W. D. Von Gonten, S. Ali, M. Ali, S. Eichman, A. Gupta, E. M. C. Kias, R. Mesdour, M. Al-Bassam, J. Degenhardt, M. Cordes, R. Suarez-Rivera","doi":"10.2523/iptc-23323-ms","DOIUrl":"https://doi.org/10.2523/iptc-23323-ms","url":null,"abstract":"\u0000 Carbonate source rock reservoirs often exhibit pronounced lamination, resulting in fine-scale facies and rock property variations that are not adequately captured by open hole logs. Precise characterization of reservoir heterogeneity across multiple scales is essential for accurate hydraulic fracture design, landing zone optimization, and ultimately enhancing well productivity. This paper presents a comprehensive workflow that utilizes specialized core-logging equipment to precisely define the thinly layered nature of the cored section, enabling centimeter-scale resolution analysis of vertical heterogeneity. The acquired data allow us to define distinct rock classes with unique and characteristics behaviors, based on multi-dimensional data patterns that mirror their unique and characteristic behaviors in rock properties. The rock classification facilitates the quantitative definition of vertical heterogeneity, capturing the fine-scale property variations within the core section. It also informs the selection of core samples for laboratory rock property characterization, ensuring that the representation of the observed variability is maximized. By integrating the multidimensional core-logging data with the discrete laboratory rock property results, we construct centimeter-resolution petrophysical and geomechanical models that result in higher fidelity reservoir characterization of thinly layered carbonate source reservoirs and more representative numerical simulations, thereby enhancing our ability to optimize hydraulic fracturing and well productivity. The workflow also includes upscaling the resolution of downhole wireline log measurements, utilizing image log measurements as structural constraints to the process, thereby enabling the derivation of high-resolution petrophysical and geomechanical properties in non-cored sections of the same well and in neighboring wells without core data. The study revealed cyclic reservoir and mechanical property variability, particularly in intervals with higher organic content, which were critical for understanding productivity, evaluating the in-situ stress, and for hydraulic fracture modeling. This level of detail in reservoir characterization is not achievable when using conventional resolution wireline logs.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"20 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527616","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}