Day 3 Wed, December 12, 2018最新文献

{"title":"Integrated Study for Well Productivity Enhancement in a Heavy Oil Reservoir in Northern Kuwait","authors":"A. Kharghoria, Khalid Ahmad, A. Al-Rabah, K. Guha, Devesh Kalia, J. Montero","doi":"10.2118/193683-MS","DOIUrl":"https://doi.org/10.2118/193683-MS","url":null,"abstract":"\u0000 Focused well reviews were carried out to identify productivity enhancement opportunities in a heavy oil reservoir in Northern Kuwait. In an integrated effort, involving multi-disciplinary and cross-functional teamwork, well and reservoir management opportunities were assessed. The goal was to recommend well restoration and optimization opportunities for short, medium and long-term implementation, thereby creating a business impact.\u0000 The process involved an in-depth comprehensive review of 59 wells. Available completion, production and pressure build-up data were tuned to analytical well models to assess individual well. Inflow performance analyses and the sensitivity check were done for drainage volume. Based on the difference between actual well performance and its estimated potential, production enhancement opportunities for the under-performing wells were estimated with proper engineering judgement.\u0000 Initial Productivity Indices (PI) were found to be consistently higher than actual well performance during the production phase, potentially due to initial flush production and short duration of the initial tests. Design of facilities, well configurations (deviated wells) and sand production were also investigated and found to have some degree of impact on well performances. Out of 59 wells reviewed, opportunities were identified for 44 wells (~75%). Out of these, 26 wells were identified for productivity enhancements methods and water shut-off/management (18 wells). Once recommendations are implemented, oil production is expected to increase by 20%.\u0000 Results obtained from the study indicates that the approach of suitable inflow management is a critical aspect to the heavy oil recovery project. This approach could be applied to other heavy oil projects with practical challenges of oil production with managed gas and water productions to maximize recovery.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127681187","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":"Methodology to Improve Techno-Economic Viability of Surfactant-Flooding in a Shallow Sandstone Heavy Oil Reservoir","authors":"M. T. Al-Murayri, A. Hassan, N. Al-Ajmi, N. Wartenberg, A. Delbos, G. Suzanne","doi":"10.2118/193665-MS","DOIUrl":"https://doi.org/10.2118/193665-MS","url":null,"abstract":"\u0000 There are ongoing efforts to assess the techno-ecnomic viability of surfactant polymer (SP) flooding to increase oil recovery by improving microscopic and macroscopic sweep efficiency. This paper sheds light on a methodology to design an appropriate SP formulation for potential deployment in the Ratqa Lower Fars (RQLF) heavy oil reservoir in Kuwait.\u0000 Besides achieving low residual oil saturation due to SP flooding under typical RQLF reservoir conditions, this study focuses on mitigating surfactant retention. Several injection strategies were investigated using alkali, adsorption inhibitors and a variety of water treatment techniques. For each scenario, a specific SP formulation was designed and evaluated through static adsorption tests using crushed reservoir rock. The two most promising options were then evaluated through coreflood experiments. The best option was selected based on in-depth chemical propagation, oil desaturation and surfactant adsorption. Finally, lab-optimization work was performed through additional corefloods to reduce chemical consumption while maintaining favorable oil recovery.\u0000 Softened seawater obtained through reverse osmosis was considered as the most appropriate water source to implement the desired SP process. Previous work revealed that the use of unsoftened seawater results in high levels of surfactant adsorption on reservoir rock. Salt addition allows applying an efficient salinity gradient post SP injection. Sodium chloride was used instead of alkali which did not exhibit any benefit in this case. A particular effort was made to reduce the amount of added salt and the corresponding formulation cost. Several injection sequences were investigated to compare polymer and SP flooding. The final coreflood experiment based on SP injection (0.6 PV of surfactant at 4 g/l), followed by a salinity gradient, and involving a polymer drive recovered 80% of the original oil in place. The promising performance of this injection sequence will be further evaluated using the results from a one-spot EOR pilot.\u0000 This EOR study on the RQLF shallow heavy oil reservoir in Kuwait provides important insights to select an appropriate surfactant-polymer injection strategy to increase oil recovery while maintaining reduced adsorption levels, thereby improving SP techno-economic viability.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130630495","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":"HSE Challenges in Thermal Operations Used for Heavy Oil Recovery","authors":"A. Qabazard, Ghadeer Al-Qattan, Sridhar Raju Ketavarapu, Nadeem Khan","doi":"10.2118/193772-MS","DOIUrl":"https://doi.org/10.2118/193772-MS","url":null,"abstract":"\u0000 Lower Faras Heavy Oil Project in Ratqa, North Kuwait of Kuwait Oil Company is one of the Major Projects in the upstream business in the Middle East. Heavy oil production from a large field is a significant challenge and involve process, which are not common for normally well-developed onshore upstream production operations personnel. There shall be a Limited/No Flow from a heavy oil well as the viscosity is high and to ensure extraction of hydrocarbon in a most possible efficient manner, thermal operations (including the steam injection) is the best option available. This additional process and associated equipment, their associated hazards are not available in the conventional oil & gas production.\u0000 Though the option of having a horizontal well with no additional steam/heat given to the reservoir, the flow from such wells can recover hydrocarbons, however it is not feasible for a commercial production. As a result, for commercial production, the reservoir is injected with steam (either cyclic or flooding) to recover the hydrocarbons in the most economical method. The steam injection method comes with a few challenges and the crux of success in Heavy oil production is to manage these hazards.\u0000 There have been several accidents that occurred worldwide in heavy oil production and related experimental activities. The root cause of accidents is generally the lack of awareness during the operation and maintenance activeness of the workforce personnel. Different incidents from world over, from the hazard identification and the operability studies undertaken during the project, suggest the various challenges that are underlying in the heavy oil operations. The challenges had been addressed systematically and design enhancement to enhance the robustness of the systems were considered whilst developing the project.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"51 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124769600","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 Function of Baffles within Heavy Oil Reservoir and their Impact on Field Development: A Case Study from Kuwait","authors":"Philip O. Benham, M. Freeman, Ian Zhang, P. Choudhary, L. Spring, G. Warrlich, K. Ahmed, Chonghui Shen, A. Sanwoolu, M. Jha, Hamad Al-Haqqan, A. Al-Boloushi, A. Al-Rabah","doi":"10.2118/193775-MS","DOIUrl":"https://doi.org/10.2118/193775-MS","url":null,"abstract":"\u0000 A heavy oil field (Field X) in Northern Kuwait is in the early stages of development but it is clear from production pilots that tight units (baffles) of variable lithology, thickness and continuity, within the reservoir will play a key role in influencing steam conformance and recovery efficiency. The high well/core density of the field’s production startup area allows re-evaluation of baffles in light of cross-discipline integration of pilot production data, petrophysical data and detailed core review.\u0000 A process was followed to update and calibrate all core descriptions against logs, follow a consistently picked set of petrophysically defined markers, compare visually defined lithofacies with log defined ones, and then map out key surfaces. The key next step is to define appropriate reservoir properties by facies/rock types, apply these to understanding pilot behaviour and predict steam conformance for Well, Reservoir and Facilities Management (WRFM) and the next phases of the wider field development planning. The field’s baffles play a role far beyond just understanding steam conformance, they are a first barrier for cap rock integrity and their presence/absence will also influence the path and rate of the aquifer influx.\u0000 The petrophysical redefinition (Baffle Quality Index) of a \"semi-stratigraphic\" interval - which will stop or slow steam migration depending on its quality and lateral extent - has enabled efficient communication about the baffle, and allowed the wider team of petroleum engineers from a number of subsurface disciplines to focus on dynamic properties impacting recovery – steam conformance, aquifer influx, windows between isolated reservoir units – and then evolve the development strategy, effectively respond to WRFM issues, optimize observation and infill well placement and increase UR in a cost effective way.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129578561","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":"Experimental Comparison between WASP and LSASF in Bartlesville Sandstone Reservoir Cores Bearing Heavy Oil","authors":"Hasan N. Al-Saedi, Yifu Long, U. Alameedy, W. Al-Bazzaz, R. Flori","doi":"10.2118/193731-MS","DOIUrl":"https://doi.org/10.2118/193731-MS","url":null,"abstract":"\u0000 Low salinity (LS) water flooding is a promising EOR method which has been examined by many experimental studies and field pilots for a variety of reservoirs and oils. This paper investigates applying LS flooding to a heavy oil. Increasing the LS water temperature improves heavy oil recovery by achieving higher sweep efficiency and improving oil mobility by lowering its viscosity. Steam flooding projects have reported many problems such as steam gravity override, but override can be lessened if the steam is is alternated with hot LS water. In this study, a series of reservoir sandstone cores were obtained from Bartlesville Sandstone (in Eastern Kansas) and aged with heavy crude oil (from the same reservoir) at 95°C for 45 days. Five reservoir cores were used in this study, and five treatments were performed. They were flooded with (a) steam; (b) formation hot water (FHW); (c) low salinity hot water (LSHW; (d) steam + FHW; and (e) steam + LSHW (so-called LSASF). The laboratory experiments showed that basic water flooding using FW recovered approximately 50% of OOIP. After that initial flood, upon switching to the various steam, FHW, LSHW, steam + FHW, and steam + LSHW treatments, the incremental oil recoveries were 5, 3.1, 6.3, 7.5, and 12% OOIP, respectively. The contact angle measurements showed that injecting steam + LSHW alters the wettability considerably more than using steam + FHW. The results of this work show that water flooding using LSHW in reservoir cores could improve oil recovery significantly because it both reduces oil viscosity and alters the rock wettability towards more water-wet. The results also showed using LSHW alternated with steam is more beneficial than using steam only or alternated with regular water due to the combined benefits of reducing gravity override and altering the wettability. Using LSHW water is more economical than using steam and gives significantly improved oil recovery, and using LSHW is more beneficial than ambient temperature LS water.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133576924","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":"Benchmarking Of Heavy Oil Fields: A Tool for Identification of Opportunities for Total Cost and Production Optimization","authors":"J. L. Ortiz-volcan, W. Al-Khamees, K. Ahmed","doi":"10.2118/193647-MS","DOIUrl":"https://doi.org/10.2118/193647-MS","url":null,"abstract":"\u0000 This paper presents a practical method for benchmarking heavy oil fields as a tool for identification of opportunities for total cost and production optimization. The method combines actual data from typical heavy oil fields to define reservoir, well and surface complexity indices, for categorizing a subject field and a total cost breakdown model to map potential risks that could cause total cost to increase, potential project/process delay and poor production performance.\u0000 The benchmarking process consists of four steps: 1) classification of a subject field using Front End Loading (FEL) and complexity indices that account for: a) reservoir structural, stratigraphic, rock, fluid, energy, static and dynamic complexity, b) well complexity and c) surface processes complexity; 2) selection of analog fields within the range of indices; 3) use of causal maps to identify causes of uncertainty and risks that impact capital expenditures (CAPEX), operational expenditures (OPEX), production losses and cycle time; and 4) a total cost stochastic model is used to generate graphs providing the position of the subject field vs. analogs.\u0000 A total undiscounted cost breakdown structure provided information on the most critical cost drivers, where significant impact corresponded to OPEX. Causal maps described typical total cost drivers for surface and subsurface. Seven most significant groups of risks are modeled to visualize the impact on cost, production losses, cycle time and health, safety and environment with recommended mitigation actions ranked by cost benefit.\u0000 A database provides information about cost of production (Capex, Opex) from heavy oil fields undergoing cold production and thermal enhanced oil Recovery well-known heavy oil production areas from Venezuela, Canada, USA and Middle East.\u0000 Heavy oil fields undergoing thermal enhanced oil recovery indicated typical ranges for Opex from 2 to 22 USD/bbl and Total Cost ranges from 10 to a maximum of 40 $/bbl. A key observation is that cost of fuel and power is the largest single OPEX cost for thermal enhanced recovery accounting for about 50%. Significant production losses are associated to failures due to corrosion and blowouts is the most significant HSE risk.\u0000 The proposed method helps benchmarking total costs in heavy oil fields, which is a task that requires lot of efforts in researching available reliable sources from technical papers, regulatory agencies, and oil industry.\u0000 Understanding causes of high cost per barrel and their relationship with uncertainties and risks for heavy oil field, is a formidable tool for multidisciplinary cost optimization as it provides a common language that understood by all disciplines involved.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114938759","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Improving the Decision Making for Heavy Oil Field Development Projects Using the Fuzzy Analytical Hierarchy Process FAHP","authors":"H. Passalacqua, A. Qubian","doi":"10.2118/193719-MS","DOIUrl":"https://doi.org/10.2118/193719-MS","url":null,"abstract":"\u0000 The selection of the best EOR option for optimizing the recovery in a field development plan is probably one of the most difficult decisions, as many parameters and options, as well as uncertainties play a role difficult to rank and characterize. This work presents the application of a new methodology, Fuzzy Analytical Hierarchy Process (FAHP), aimed to select the best EOR option, illustrating its practical application to a heavy oil field development case.\u0000 In order to rank efficiently prospects opportunities and exploitation scenarios the most common approach is the evaluation based on economical parameters. However, technical parameters like well-types options, facilities configurations, transport options, operability, and reliability, are not strictly, nor solely economical parameters, hence, not easily considered during the screening and selection phases of the FEL (Front-End-Loading) process. When the number of options and parameters becomes very large, the human judgement must be supported by some kind of logical methodology or Multiple Attribute Decision Making (MADM) methodology.\u0000 One of these methodologies is the FAHP (Fuzzy Analytical Hierarchy Process) which is a modification of the Analytical Hierarchy Process (AHP) tested previously for the development of a heavy oil field in the pre-FEL stage aiming to improve the decision-making process, including technical elements in addition to the conventional economic parameters.\u0000 The application of the FAHP technique is analyzed in this work, deriving conclusions of interest when dealing in field development decisions that require decisions from a group of experts.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"723 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115624688","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":"Land Controlled Source Electromagnetic Technique for Shallow Viscous Oil Reservoir Characterization of North Kuwait","authors":"Rajive Kumar, Ren Biao, A. Khalid","doi":"10.2118/193734-MS","DOIUrl":"https://doi.org/10.2118/193734-MS","url":null,"abstract":"\u0000 Controlled Source Electromagnetic (CSEM) method provides an effective imaging tool for the reservoirs characterized by distinctive resistivity signature, such as lithological change or fluid saturated channels. Acquisition, processing and modeling of CSEM data provide us an effective complementary information to seismic in characterization and potentially production of viscous oil from the shallow reservoir. CSEM methods using electric dipole sources are very sensitive to thin resistive layers similar to shallow clastic reservoir of North Kuwait. Prior to CSEM survey, the sensitivity of this method to presence of viscous oil bearing layers was tested through synthetic simulation study utilizing several well logs of shallow clastic reservoir. Feasibility study highlighted the good sensitivity of CSEM to resistive shallow clastic reservoir.\u0000 In CSEM survey layout, the source position started with offset from the receiver spread progressing through the spread and move to the opposite side by same offset. The electric field data are recorded on 100m dipoles, at continuous 100m interval, with 100m between receiver lines. Transmitter dipoles were also 100m, but spaced at 300m intervals along line. Data processing is carried out in the frequency domain. Source and receiver calibration functions are included in the process along with all geometry data. Amplitude and phase response is obtained for each source and receiver combination at multiple frequencies. Measured amplitude and phase values varied depending on the source-receiver separation and more importantly on the subsurface resistivity distribution between source and receiver.\u0000 The CSEM synthetic responses obtained through forward modeling are compared with observed processed data to perform a further quality control step and start a qualitative data imaging. In fact, the measured electric field amplitude and phase deviate from the synthetic data as much as true subsurface resistivity distribution deviates from reference model. Another essential step in CSEM data analysis consists of inverting the data to infer a resistivity model that could fit the observed measured data. We followed an incrementally more complex workflow from 1D CSEM laterally constrained anisotropic inversions to 3D anisotropic CSEM inversion. 3D inversion of co-located MT data and 1D CSEM inversion helped to build a reliable a priori model.\u0000 The output anisotropic resistivity earth model showed good consistency with the previous step qualitative imaging results and with the available resistivity logs. Resistivity volume obtained from 3D CSEM inversion can be interpreted to correlated resistivity lateral variation in depth and space with known features to infer rock physics variations at the shallow reservoir levels. This information, together with the results of non-seismic data acquired at the same time and of the seismic dataset has helped in characterizing the shallow clastic viscous oil reservoir.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131271061","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":"Opportunity Assessment of a Deep Extra Heavy Oil Green Field: Scenarios for Life Cycle Cost Optimization Under Uncertainty and Risk","authors":"J. L. Ortiz-volcan, K. Ahmed, S. Azim, Y. Issa, R. Pandit, A. Al-Jasmi, M. O. Hassan, A. Sanyal, S. Taduri","doi":"10.2118/193675-MS","DOIUrl":"https://doi.org/10.2118/193675-MS","url":null,"abstract":"\u0000 Selecting the optimum combination of technologies is a critical and challenging activity while conducting the opportunity assessment under high levels of uncertainty in a deep (~9000 feet) extra heavy oil green field transitioning between appraisal and development phases. Low mobility requires enhanced oil recovery to be addressed early in the life of the field, so selected wells can be drilled and completed in selected locations to reduce uncertainty about producibility and flow assurance.\u0000 This paper presents a practical approach to opportunity assessment based on Front End Loading (FEL) methodology, with three major steps: 1. Evaluation of known data, determination of complexities, uncertainties and risks by benchmarking with selected field analogs, 2. Identification of all potential technology options and 3. Definition of feasible appraisal and development scenarios and a high-level road map including estimates of life cycle cost opportunities for optimization.\u0000 We found reservoir static complexity medium, well complexity low, and reservoir dynamic complexity high. FEL definition indices for reservoir and well indicated low reservoir definition and acceptable index for wells. These complexity and definition indices were used for conducting benchmarking with three analog fields providing references for risks and ranges of production, recovery and total cost.\u0000 After multidisciplinary analysis with participation of 35 specialists organized into three clusters (subsurface, well and surface), 100 challenges (72 risks and 28 uncertainties) were identified, analyzed and ranked. Assessment of 36 parameters used for Enhanced Oil Recovery (EOR) screening were assessed from uncertainty perspective with preliminary selection of 7 potential EOR methods. Final integration was achieved with identification of 110 technology options for 30 key decisions, finally selecting best suitable options for 4 potential development chronological scenarios.\u0000 Results are presented in a cost breakdown structure reflecting the most critical cost drivers, where high percentage corresponds to OPEX affected by identified risks and causal maps describes effects on total costs for subsurface, well and surface. We modeled all significant risks by visualizing its impact on total cost and we defined the mitigation actions ranked by risk adjusted stochastic economics performed as input for decision-making.\u0000 This paper demonstrates that understanding the root causes of high cost per barrel and their relationship with uncertainties and risks during early stages of a heavy oil field life cycle, provides a common language for multidisciplinary cost optimization, and facilitates communication and involvement of all disciplines.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115793181","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 Computational Fluid Dynamics Model for Simulating the Rotating Disk Apparatus","authors":"A. Kotb, Mahmoud T. Ali, A. Ezzat, A. Elwany, H. Nasr-El-Din","doi":"10.2118/193739-MS","DOIUrl":"https://doi.org/10.2118/193739-MS","url":null,"abstract":"\u0000 Reaction kinetics between calcite and acid systems has been studied using the rotating disk apparatus (RDA). However, simplifying assumptions have been made to develop the current equations used to interpret RDA experiments to enable solving them analytically in contrast to using numerical methods. Experimental results revealed inadequacy of some of these assumptions, which necessitates the use of a computational fluid dynamics (CFD) model to investigate their impact on the RDA results. The objectives of the current work are threefold: (1) develop a CFD model to simulate the reaction in the RDA, (2) Identify the error associated with the assumptions in the original equations, and (3) develop a proxy model from the results that can accurately represent the reaction in the RDA.\u0000 In developing the CFD model, the averaged-continuum approach was used to simulate the chemical reaction on the disk surface. Both Newtonian and non-Newtonian fluids were studied to investigate the adequacy of the equations’ assumptions. To validate the model, simulations were compared with experimental results. Experiments were run at 0.25, 0.5, 1, and 1.25M HCl with marble using the RDA at 250°F. Rotation speeds of 200, 400, 600, and 1,000 rpm were tested at each acid concentration. The diffusion coefficient was then calculated. Parameters of the CFD model were then adjusted to match the rock dissolved throughout the RDA experiments.\u0000 The rock dissolved in the disk from the CFD model matched the results from the RDA experiments. The transition from mass-transfer to the kinetics-limited reaction behavior was captured by the CFD model. The velocity and viscosity profiles for both Newtonian and non-Newtonian fluids showed the effect of the container's boundaries on the flow. Results indicate that this effect is pronounced in the case of Newtonian fluids at high rotational speeds. Moreover, the impact of varying viscosities in the case of non-Newtonian fluids resulted in errors in estimating the reaction kinetics. Finally, a proxy model was obtained to reduce the computational time involved in accurately simulating the experiments.\u0000 The present work developed the first CFD model to accurately evaluate reaction kinetics and diffusion coefficient in the RDA with minimum assumptions. More specifically, the model relaxes the infinite acting, constant fluid properties, and constant reaction surface area assumptions. Finally, the proxy model obtained results in reduced computational time with minimal compromise on accuracy.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"135 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132368609","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}