Day 2 Tue, March 14, 2023最新文献

{"title":"Accurate Identification of Gas-Bearing Formation in a Mature Field Using Pulsed Neutron Logs Prevented Well Abandonment","authors":"S. Sahu, A. Tyagi, Yonghwee Kim, Arjun Puri","doi":"10.2118/214153-ms","DOIUrl":"https://doi.org/10.2118/214153-ms","url":null,"abstract":"\u0000 Operators typically update formation fluid saturation from producing wells as production impacts changes in formation fluid type and volume. An operator in India deployed a multi-detector pulsed neutron well logging tool on one of the old wells in a mature field to evaluate saturation profiles across multiple clastic formations. Production from the subject well had ceased due to water loading. The objective of the logging was to identify possible bypassed hydrocarbon zones before the operator decided on the well abandonment.\u0000 A multi-detector pulsed neutron tool acquired a salinity-independent gas-sensitive time-based measurement from short-spaced and extra-long-spaced gamma-ray detectors. In addition, inelastic energy spectra-based carbon/oxygen (C/O) ratios were recorded to quantify formation oil saturation in a low water salinity environment. Another critical component in the saturation analysis workflow was the forward modeling of tool responses. We used the Monte Carlo N-particle (MCNP) stochastic method to predict gas-sensitive and C/O ratio responses in logging conditions.\u0000 We had limited information on well conditions, such as cement bond condition and formation fluid properties, as no recent well logging was carried out to evaluate these. Thus, we performed saturation analyses in various conditions to reduce uncertainties in the results, including well-cemented, partially-cemented, and uncemented annulus conditions and different oil and gas densities.\u0000 The analysis results identified one shallow sand unit containing gas. The sand was initially considered a water-dominant zone because the same zone produced water from adjacent wells. We evaluated the uncertainty in the gas saturation calculation attributed to cement bond quality and formation gas density. This helped to remove uncertainties in cement bond conditions and in-situ gas density on gas saturation. The identified sand unit was perforated and produced a large amount of gas. The accurate result of the gas saturation analysis saved the well from abandonment and increased reserves and production capacity. Additionally, the analysis revealed that water-filled formations were predominant in other sands. The C/O log analysis showed no bypassed oil in the lower sands.\u0000 This paper further discusses case studies on candidate selection for pulsed neutron well logging, uncertainties in formation parameters, and the implications for saturation results.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"408 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117098118","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 Digital and Real-Time Technologies in Deepwater Drilling Environment Operations for Performance Enhancement and Efficient and Accurate Decision-Making Process.","authors":"Andres Felipe Nunez Davila, J. R. Lopez, Lucas Rossi, Graham Smith","doi":"10.2118/214280-ms","DOIUrl":"https://doi.org/10.2118/214280-ms","url":null,"abstract":"\u0000 In recent years, the oil and gas industry has evolved and now requires the application of digital solutions. The deepwater environment is no exception. In an integrated project in the Gulf of Mexico, a long-term commercial relationship was established. Different technologies were implemented that have positively affected the overall performance, focusing on risk management, efficiency, and establishing a more accurate decision-making process. This paper describes how digital solutions are integrated into the project to better detect undesirable events and offer ways to further enhance well performance.\u0000 New technologies have been implemented to optimize the operations while reducing nonproductive time and undesirable events, without adding additional operational risks. The strategy employed resulted from the integration of the real-time monitoring in conjunction with the digital technologies. Monitoring drilling fluid properties in real time through the application of the semiautomatic rheometer provided the required input to maintain optimum fluid conditions and keep the required hole clean. The ultimate objective of drilling operations is to ensure well integrity before the well is placed in production. Cementing operation real-time solutions provide quick and accurate results after the job is completed, assuring the job objectives.\u0000 In parallel, to eliminate inefficiencies and capture invisible lost time, the implementation of the multiwell performance analysis and benchmarking tool enables project process evaluation. This evaluation features both a micro and macro perspective. The evaluation takes into consideration the routine and nonroutine operations executed daily. In the initial stage, the solution supports the definition of the baseline and benchmark required. It will also determine project progress and further define the most suitable technologies needed to capitalize on improvement opportunities.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117001987","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":"Productivity and Cost Comparison Between Radial-Borehole Fracturing and Horizontal Well Fracturing in Shale Oil Reservoir","authors":"Jiacheng Dai, Zeyu Zheng, Tianyu Wang, Gensheng Li","doi":"10.2118/214197-ms","DOIUrl":"https://doi.org/10.2118/214197-ms","url":null,"abstract":"\u0000 Given the abundant reserves, shale oil resource has great potential for future utilization. However, shale formation is often characterized by complex geological structures and developed stratification, which greatly restricts the formation stimulation performance of volumetric fracturing along the vertical direction in horizontal well and therefore raises development costs. To address such issues, a new method that utilizes radial-borehole fracturing based on vertical well is proposed to extract shale oil. This paper describes the fracturing network under radial borehole fracturing. A numerical model that considers shale formation, hydraulic fractures, and the wellbore is built to predict the productivity of radial-borehole fracturing and horizontal well fracturing. Moreover, a simplified cost evaluation model is built, respectively.\u0000 Furthermore, this paper analyzes the influence of different well patterns, fracture heights, and Kv/Kh ratios on radial-borehole well productivity and compares the cost-effectiveness of a radial-borehole fractured well and horizontal well fracturing. Results indicate that radial-borehole fracturing is capable of eliminating the constraints of fracture height and thereby improving stimulation performance; more radial boreholes and main wells result in more oil production; in addition, as the fracture height decreases, the ratio Kv/Kh is closer to 0, it is more recommended to use radial borehole fracturing. A case study of Eagleford shale oil reservoir is herein carried out: The 9-vertical well, 3-layer, 4-lateral radial borehole fracturing brings the same oil production as the 3-horizontal well multistage fracturing (open hole completed) does, while the former costs 0.36 M$ less of the latter. Using radial borehole fracturing method to develop shale oil is proposed in this paper. The results can provide new insight into the effective development of shale oil resources at low cost.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"116 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121693059","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":"Implications of Wellbore-Fracture Separation on Temperature Log Interpretation Studied Through Numerical Modeling and Field Measurements and Observations","authors":"A. M. Khan, Abdullah Binziad, Abdullah Alsubaii","doi":"10.2118/214170-ms","DOIUrl":"https://doi.org/10.2118/214170-ms","url":null,"abstract":"\u0000 Temperature logging is an old technique that quantifies fracture height based on cooldown anomalies. Warm anomalies are very frequently observed in post-fracturing measurements. One of the reasons for these anomalies is misalignment of the wellbore with the fracture, which depends on the geometry of wellbore and preferential fracture plane. A systematic study is presented here to avoid misinterpretation of fracture height.\u0000 Two mathematical tools were coupled: (1) a geometrical resolution of the 3D space around the wellbore and (2) a numerical scheme solving the heat transfer partial differential equation (PDE) in dimensionless form to simulate temperature evolution around the wellbore. Finally, the findings were tested and corroborated with a few field cases in deep, hot, clastic reservoirs. The temperature log was conducted with three passes and was used for interpretation in deviated wellbores.\u0000 The first tool utilized the wellbore deviation, wellbore azimuth, and fracture azimuth to resolve the relative positions and detailed geometry in 3D space. The tool yielded the fraction of total fracture height that will be coincident with the wellbore for a given set of inputs. The outputs were then coupled with the numerical tool with an explicit finite difference code to solve the relevant PDE with appropriate boundary conditions for the given geometrical space for the angled/separated fracture. The results showed that the further the fracture separates from wellbore, the more difficult it is to observe cooldown if the temperature logging is conducted soon after fracturing. Delaying the temperature passes allows the cold front from fracture to move towards wellbore and is a viable solution to capture cooldown, as seen from field measurements and validated by the model. The field cases demonstrated some complicated temperature behaviors, and the understanding developed from the modeling tools aided in interpreting the anomalous trends. The possibility of constructing pseduo temperature logs, lowering the number of passes, and extending the approach for multiple applications is discussed.\u0000 The innovative approach avoids pitfalls of false indications of fracture containment in deviated wells. It can be used to improve the utility of high-resolution temperature logging data to enhance efficiency.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"116 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132324005","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":"Intelligent Wireline Formation Tester Evaluation of Low-Permeability and Low-Resistivity-Contrast Formation with Detailed Digital Planning.","authors":"Lijun Guan, Xiannan Wang, Jian Wang, Gao Bei, A. Gisolf, Zhaoya Fan, A. Partouche, M. Kristensen, Shiju Li, Li Chen, Jichao Chen","doi":"10.2118/214252-ms","DOIUrl":"https://doi.org/10.2118/214252-ms","url":null,"abstract":"\u0000 Exploration and development drilling in offshore China is extending to Paleogene formations that are characterized by low-resistivity-contrast and low-permeability rocks. These formations have become a focus for increasing reserves and production. During exploration activities, these low-resistivity, low-formation-contrast formations have been critical and challenging for formation evaluation because the geological structure and lithology are more complex than in previously discovered fields. Differentiating hydrocarbon from water using petrophysical interpretation has a large uncertainty in these formations. Confirming the fluid type using conventional formation testing technology has been extremely challenging because the produced fluid is mainly mud filtrate, which is of no use for fluid confirmation.\u0000 The dual-flowline architecture of the intelligent formation testing platform (IFT) is designed to systematically address shortcomings of legacy technology, enabling focused sampling in the tightest conventional formations. Specialized digital planning of the numerical flow models by adding a brine tracking facility and enumeration initialization was performed to (a) compare and benchmark the cleanup performance of conventional radial 3D probe and new focus radial probe; (b) simulate multiple scenarios including hydrocarbon-water transition to understand the salinity changes while pumping in various water saturation circumstance and optimize operational planning by quantifying cleanup time uncertainties even in two-phase fluid reservoir; and (c) history match the sampling drawdown, flow rate, and salinity change with actual sampling data and provide real-time answers to help accelerate the decision-making cycle.\u0000 This dedicated design resulted in increased efficiency in water sampling compared to previous testing done by the operator. Whereas previous gas-water transition zone sampling was challenging because high water-based mud filtrate fractions masked the presence of formation water and formation hydrocarbon, the focused radial probe, combined with state-of-the-art resistivity measurements and prejob modeling of salinity change, allowed identification of gas and the measurement of formation water resistivity in a multiphase flow environment. The formation testing of these low-resistivity-contrast and low-permeability formations enabled acquisition of a 2% contaminated formation water sample in 140 minutes with formation mobility of 1 md/cP. The gas-water zone was confirmed from a dual-flowline resistivity measurement and a hydrocarbon show in mobility of 1.4 md/cP. The intelligent wireline formation testing platform enabled high-performance and efficient collection and identification of formation water and gas in a low-mobility low-resistivity-low-contrast formation.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129419068","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":"Automated Well Log Interpretation Through Machine Learning","authors":"Wassem M. Alward, Mohammed Al-Jubouri, Ling Zongfa, Xu Xiaori, Xu Wei, Zhao Yufang","doi":"10.2118/214055-ms","DOIUrl":"https://doi.org/10.2118/214055-ms","url":null,"abstract":"\u0000 Well logs present a concise, in-depth representation of formation parameters. These logs allow interpreters to identify different rock types, distinguish porous from non-porous rocks, and quickly identify pay zones in subsurface formations. The ability to interpret well logs is largely dependent on the interpreter's ability to recognize patterns, past experiences, and knowledge of each measurement. Traditionally, logs were manually corrected for anomalies and normalized at the field scale, which is a time-consuming and often subjective approach. This is especially true for mature fields where log data has been collected from multiple sources. However, the future of petrophysical evaluation is moving towards increased efficiency, accuracy, and objectivity through smart automation.\u0000 In this paper, we demonstrate the application of machine learning algorithms to automate well-log processing and interpretation of standard log measurements as well as nuclear magnetic resonance (NMR) using data acquired in one of the fields in Iraq. Standard logs such as density, sonic, neutron, gamma ray, etc are classified using machine learning (ML) algorithm into a set of classes that are converted to zones to drive petrophysical interpretation. This novel application of ML algorithm uses cross-entropy clustering (CEC), Gaussian mixture model (GMM), and Hidden Markov Model (HMM) which identifies locally stationary zones sharing similar statistical properties in logs, and then propagates zonation information from training wells to other wells. The training phase involves key wells which best represent the formation and associated heterogeneities to automatically generate classes (clusters), the resulting model is then used to reconstruct inputs and outputs with uncertainty and outlier flags for cross-checking and validation. The model is then applied to predict the same set of zones in the new wells that require interpretation and predict output curves. The main advantage is reducing the turnaround time of the interpretation and eliminating subjective inconsistencies often encountered with standard interpretation approaches.\u0000 For multi-dimensional data such as NMR, several ML methods such as Parallel Analysis, Factor Analysis, and Cluster Analysis were applied to (a) determine the optimal number of modes to retain in the input NMR T2 distributions, these modes are the underlying poro-fluid constituents affecting NMR data over the entire interval b) decompose T2 distribution into these modes c) compute poro-fluid constituents volumes and cluster it into the same number of groups as the number of factors. This workflow helps to extract maximum information from multi-dimensional NMR data and eliminates the need for any a-priory assumptions, such as T2 cut-offs. We present the results of these methods applied to data acquired across the cretaceous successions in the south of Iraq to speed up the petrophysical analysis process, reduce analyst bias, and improve consiste","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131819657","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Integrated Reservoir Characterization in Overpressure and Complex Sandstone Reservoirs for Hybrid Reservoir Modeling and Oil Productivity","authors":"M. Gibrata, G. Ameish, Yanfidra Djanuar, Mohammad Lamine, Jose Lozano","doi":"10.2118/214258-ms","DOIUrl":"https://doi.org/10.2118/214258-ms","url":null,"abstract":"\u0000 A Reliable reservoir characterization and model are useful for reservoir development in overpressure and complex reservoirs. The field has overpressure, multi fluid contacts, multi reservoir subunits, structural and stratigraphic sand discontinuities. The reservoir properties and quality decrease with increase of depth due to overburden compaction. However rock quality is useful for oil in place and productivity. Therefore, reliable reservoir characterization in deep reservoirs and estimation of fluids in place requires an integrated subsurface data approach.\u0000 Overpressure reservoir has been observed and evaluated in some reservoirs, it tends to preserve porosity and has sufficient permeability for oil productivity from the deep reservoirs. Image resistivity/density log and chromatography data have been used to identify minor fault, gas/fluid evaluation and update the reservoir model. An integrated petrophysical evaluation has been implemented in reservoir characterization. A reliable in-house permeability log has been developed from porosity, clay bound, pore size, core and mobility data. It has used the of hybrid saturation height model that based on SCAL data including capillary pressure and Relative Permeability data for every reservoir rock type and fluid contacts for subunits.\u0000 The advanced evaluation approach of subsurface and well test data has been used to provide reliable and good of reservoir properties and results on porosity, permeability, fluid contacts, reservoir rock type and initial water saturation in deep and overpressure reservoirs. The saturation height model (SHM) has been used, a quasi-SHM for unavailable core data in deep reservoir and PVT data have been used in the evaluation. The suitable open and cased hole logs data such as image resistivity/density, chromatography, pulse-neutron capture and production logs have been used to verify fault, fluid contacts, contribution, water saturation changes and production optimization. For every reservoir subunits, the formation pressure has been used to identify an initial oil water contact, reservoir subunits evaluation and thus it has provided SHM for complex reservoir modeling. The study has provided reliable reservoir characterization, reservoir modeling and for the development for multi-layers, over pressure and complex sandstone reservoirs. The high overpressure deep reservoirs have contributed for good oil productivity. It provides support to improve oil recovery from reservoirs and future plan for reservoir development target. Therefore the integrated reservoir evaluation approach has provided reliable assurance and important benefits for reservoir characterization, optimization and reservoir management.\u0000 The integrated hybrid approach in this paper shows the value of advanced reservoir characterization in overpressure and faulted complex reservoirs. It has utilized the integration updated open and cased-hole data, gas/fluid contacts, stress direction, advanced permeabilit","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"217 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130376249","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 the Complete History Flow to Avoid the Misleading Boundary Effects in Well Testing","authors":"Yanfang Chen","doi":"10.2118/214248-ms","DOIUrl":"https://doi.org/10.2118/214248-ms","url":null,"abstract":"\u0000 The objective of this paper is to correct the inappropriate common practice of using the incomplete flow history before the main Build-up in well test interpretation and pressure transient analysis for eliminating the misleading understanding of boundary effects behavior.\u0000 Generally, during a short-term well test, wells are usually in the transition flow regime. And bottom hole and well head pressure change noticeably with time especially in the lower permeability reservoirs. The length of the flow period should be long enough to attain a radius of investigation and stabilize the well production and fluid composition for evaluating well deliverability and flow performance as well as determine critical rate for water or gas coning etc. The unknown duration of flow period mainly is based on the inaccurate analogy in well test design. It is widely recognized that the determination of enough Build-up period is more important in the reservoirs with low permeability for investigating of boundary effects. While the significance of the proper length of pressure drawdown or flow period is usually overlooked in PBU interpretation.\u0000 PBU interpretation with main flow period and final Build-up period in the well surveillance stage is a common practice. After the pressure gauges are retrieved, the on-site interpretation will be conducted in accordance with data collection with no regard to the flow history prior to PBU. During this process, the misleading boundary effects are observed which might lead to misinterpretation that the pressure behavior is influenced by boundary configuration, interference from offset wells, reservoir heterogeneity and fluid OWC in late time regime. In addition, the determination of reservoir permeability and skin factor as well as drainage area and boundary effects identification all require the proper input of complete flow history. Therefore, the complete flow history must be utilized appropriately to avoid the misleading boundary effects in well testing for more accurate interpretation of reservoir and its boundary characterization as well as hydrocarbon volume estimation. The significant difference will be clarified and demonstrated by comparison and sensitivity analysis between the different length of flow duration scenarios for better understanding the misleading boundary effects so as to avoid the misinterpretation and inappropriate decision-making.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132629740","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":"Onshore Abu Dhabi Carbonate Saline Aquifer CO2 Storage Site Selection - An Integrated Technical Feasibility Study","authors":"Siqing Xu, M. Baslaib, A. BinAmro, Aaesha Keebali","doi":"10.2118/214030-ms","DOIUrl":"https://doi.org/10.2118/214030-ms","url":null,"abstract":"\u0000 Carbon Capture and Storage (CCS) technologies help reduce carbon dioxide emissions from large point sources, such as power plants, gas processing facilities and other industrial facilities. It involves capturing CO2 emissions, transporting the captured CO2 to storage location, and securely storing underground for a long time. The term permanent storage is very often used. CCS technologies involving storage in underground geological formations are well established, and there are current a number of such ongoing projects, together with an increasing number of projects in the planning phase.\u0000 Saline aquifers can be leading CO2 permanent storage candidates. Deep saline formations or deep brine reservoirs exist world wide, making them potentially accessible CO2 storage candidates. However, not all saline formations can be considered suitable for long term commercially viable storage candidates. A number of critically important factors must be taken into account/verified, for example, CO2 containment assurance, social and environmental impact, and project commercial aspects. A project feasibility is normally recommended as a first step, whereby potential saline aquifer candidates are screened, ranked against for example accepted best international guidelines and criteria. Detailed feasibility study can follow once top ranked suitable candidate(s) are identified.\u0000 A comprehensive multi-discipline study was carried out looking at the potential for CO2 sequestration in deep saline aquifer formations within onshore Abu Dhabi. The area of interest is very large in scale (regional scale) and consists of multi stacked saline aquifer formations. The study has the added complexity that the same saline aquifer formations may be shared with near-by hydrocarbon exploration and production activities. The objectives were to analyze available geological data, oil field production and injection data, identify key constraining factors especially concerning CO2 containment assurance, arrive at regional storage capacity range estimates, and demonstrate site CO2 storage feasibility.\u0000 Considerable amount of geological data and studies are available, which can assist with regional Onshore Abu Dhabi saline aquifer formation geological characterization for CO2 storage assessment. The characterization synthesis forms the study basis. Dedicated regional scale 3D saline aquifer formations compositional dynamic models were constructed, capturing the key CO2 sequestration processes/mechanisms. Storage capacity estimates were obtained from the dynamic model – the results will be published separately. A comprehensive Risk Assessment was carried out. Risk assessment approach and MMV plan development are shared.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130777342","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":"Factors Affecting CO2 Absorption in Water Using a Gas Absorption Packed Column","authors":"Maitha Zuhair Al Hadhrami, Mohammad Abdel Fattah Alalaween, Antonio Lugay Mateo, Abdulmajeed Abdulla Al Blooshi, Khalid Yousuf Kahoor, Saeed Ali Al Yileili, Rashid Salem Al Suwaidi","doi":"10.2118/214122-ms","DOIUrl":"https://doi.org/10.2118/214122-ms","url":null,"abstract":"\u0000 Population growth is directly associated with increase in energy demand. Amplification in industrial activity has led to a drastic escalation in greenhouse gas emissions causing global warming. The major gas involves carbon dioxide, accounting for 76% emitted from different industrial sectors. The oil and gas industry alone is responsible for 90% of these emissions. Removing CO2 is a vital process in the gas industry which must be undertaken. Carbon capture utilization and storage (CCUS) technologies have evolved through the years due to the necessity of the current world-wide shared goal, to attain net zero.\u0000 Several combustion methods have been developed to capture CO2 during actual operations at fossil fuel power plants, at natural gas processing plants and at coal gasification plants. However, methods that are based on chemical and physical absorptions have been most widely used. One example is the gas absorption-based method which requires low energy consumption and has been proven to be cost-effective. Using certain water types, mixed with minute concentration of chemical solvent, it can readily absorb CO2. This approach will be used in the following research study to investigate gas absorption rate using different water samples that pass through a packed column, thereby enhancing the mass transfer of gas component.\u0000 In this study, the gas absorption experiments were carried out using SOLTEQ gas absorption unit containing DN 80 packed column with glass Raschig rings and with an effective column height of 1000 mm (Figure 1). Under constant operating conditions, the temperature and pressure were set to 24°C and 2 bars, respectively, to investigate the impact of pH level and conductivity of various types of water on CO2 absorption at different gas flow rate.\u0000 The statistical analysis indicates that TDS and conductivity have a stronger correlation with gas absorption (P=0.99) than pH (P=0.76). The average CO2 absorption of the three samples at different flow rates (e.g., 0.8, 1.3, and 2.2 LPM) ranged from 36.40 in sample 1 to 69.50 in sample 2 at flow rate 2.2 LPM. Overall, samples 2 and 3, neutral to base with pH value of 7.25 and 8, respectively, have a statistically significant negative correlation with average CO2 absorption, whereas the acidic (pH = 5.42) sample 1 has significant positive correlation between the two variables (R2 = 0.99).\u0000 Overall, samples 2 and 3, which are neutral to base with pH values of 7.25 and 8, have a statistically significant negative correlation with average CO2 absorption. In contrast, the acidic (pH = 5.42) sample 1 has a significant positive correlation between the two variables (R2= 0.99). This study provides optimal operating conditions for the CO2 absorption process. However, additional research is required to investigate the effect of other physical and chemical properties of water on CO2 absorption.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133821647","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}