Day 2 Wed, April 27, 2022最新文献

{"title":"Produced Water Treatment and Utilization: Challenges and Future Directions","authors":"S. Eyitayo, M. Watson, O. Kolawole","doi":"10.2118/209310-ms","DOIUrl":"https://doi.org/10.2118/209310-ms","url":null,"abstract":"\u0000 Produced water is naturally occurring water that is produced as a byproduct during the exploration and production of oil and natural gas from the subsurface system. Produced water brought to the surface contains high saline content and may also contain Naturally Occurring Radioactive Material (NORM). Therefore, the efficient treatment, use, and disposal of produced water remain a critical issue for the energy industry with environmental and human health implications. Over the years, researchers have presented numerous treatment technologies ranging from physical, chemical, and biological perspectives. Some industries have combined one or two of these methods to improve the treatment quality of produced water required for distinct purposes, and these practices have been extended to the energy industry. As the energy industry strives to sustain production capacities and maintain or increase profitability in this energy-transition era, water production is also rising while there is a reduction in its re-purposing and utilization for energy and environmental industries. Our study focuses on over 100 studies conducted over the past five decades. This study presents a comprehensive overview of the produced treatment methods, challenges regarding the execution and implementation of these methods in the energy industry. We highlight the important fundamental questions that are yet to be addressed and propose new directions for more environmentally friendly and economically viable solutions for the treatment and use of produced water.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"145 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116863575","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 EDFM+DPDK Hybrid Workflow for Hierarchical Treatment of Fractures in Practical Field Studies","authors":"M. Hui, Bradley T. Mallison, Sunil G. Thomas, Pierre Muron, Xu Xue, Matthieu Rousset, E. Earnest, H. Vo, Keith Ramsaran, C. Jensen","doi":"10.2118/209293-ms","DOIUrl":"https://doi.org/10.2118/209293-ms","url":null,"abstract":"\u0000 Natural fracture systems comprise numerous small features and relatively few large ones. At field scale, it is impractical to treat all fractures explicitly. We represent the largest fractures via Embedded Discrete Fracture Modeling (EDFM) and account for smaller ones using a dual-porosity, dual-permeability (DPDK) idealized representation of the fracture network. The hierarchical EDFM+DPDK approach uses consistent discretization schemes and efficiently simulates realistic field cases. Further speed-up can be obtained using aggregation-based upscaling. Capabilities to visualize and post-process simulation results facilitate understanding for effective management of fractured reservoirs. The proposed approach embeds large discrete fractures as EDFM within a DPDK grid (which contains both matrix and idealized fracture continua for smaller fractures), and captures all connections among the triple media. In contrast with existing EDFM formulations, we account for discrete fracture spacing within each matrix cell via a new matrix-fracture transfer term and employ consistent assumptions for classical EDFM and DPDK calculations. In addition, the workflow enables coarse EDFM representations using flow-based cell-aggregation upscaling for computational efficiency, as well as finite-volume tracer-based flux post-processing to analyze production allocation and sweep. Using a synthetic case, we show that the proposed EDFM+DPDK approach provides a close match of simulation results from a reference model that represents all fractures explicitly, while providing runtime speedup. It is also more accurate than previous standard EDFM and DPDK models. We demonstrate that the matrix-fracture transfer function agrees with flow-based upscaling of high-resolution fracture models. Next, the automated workflow is applied to a waterflooding study for a giant carbonate reservoir, with an ensemble of stochastic fracture realizations. The overall workflow provides the computational efficiency needed for performance forecasts in practical field studies, and the 3D visualization allows for the derivation of insights into recovery mechanisms. Finally, we apply a flux post-processing scheme on simulation results to understand expected waterflood performance.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128639773","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Modeling Gas Migration During a Gas Kick","authors":"Ali Zankawi","doi":"10.33915/etd.10344","DOIUrl":"https://doi.org/10.33915/etd.10344","url":null,"abstract":"\u0000 Gas kick is an undesirable problem in the drilling process, which can potentially lead to a blowout. The primary intent of this study is to highlight gas migration and its effect on gas kick mitigation approaches that would benefit the drilling process. The integrated analysis provides valuable insight regarding parameters promoting efficient drilling processes, minimizing the risk of gas kicks. This study aimed to investigate the impact of critical parameters on gas migration during the gas kick in both water-based mud and oil-based mud and to promote an understanding of the dynamics of choke pressure, gas velocity, and bottomhole pressure based on completion and reservoir parameters.\u0000 This study reveals various factors affecting gas migration during gas kicks, characterized by different interactive parameters. These parameters include wellbore configuration, mud density, kick volume, drill-pipe size, reservoir temperature, and oil-water ratios. A commercial multiphase dynamic well control simulator was used in this study to develop two base models: Oil-Based mud (OBM) and Water-Based mud (WBM). The models were used to perform several parametric studies to investigate the impact of critical parameters on gas migration during the gas kick. Each type of mud acted differently and affected the gas migration discussed in this study. The study explicitly illustrates the different outcomes for each model during gas migration.\u0000 The parameters that range from most effective to least effective on gas migration are wellbore configuration, kick volume, drill-pipe size, mud density, and reservoir temperature in WBM, while in the OBM, the parameters that range from most effective to least effective are wellbore configuration, kick volume, drill-pipe size, oil-water ratio, mud density, and reservoir temperature. However, the main differences are the gas rise velocity and time in the base models. In water-based mud, the gas velocity is 97.8 ft/min, while the gas velocity in oil-based mud is 75.6 ft/min. The gas is discharged from the well within 48.2 minutes in the water-based mud, while the oil-based mud takes 115.7 minutes.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125311704","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":"Improved Reverse Osmosis Membranes for Treating Produced Water","authors":"R. Franks, Xiaofei Huang, Craig Bartels","doi":"10.2118/209256-ms","DOIUrl":"https://doi.org/10.2118/209256-ms","url":null,"abstract":"\u0000 For many years, reverse osmosis (RO) elements have been used in the treatment of produced water, including at several sites in California. The RO reduces salts and organics in the produced water to a level that allows for disposal or reuse. The RO elements used to treat produced water are similar in chemistry and construction to the conventional seawater RO membrane. But compared to seawater, the characteristics of produce water are unique and varied. The conventional seawater membrane comes with pressure and temperature limitations that restrict its ability to treat a wide range of produced waters. Specifically, conventional membranes have a temperature limit and a pressure limit. Only a portion of the produce waters needing treatment fall within the membrane's temperature and pressure limitations. Many produced waters, including produce waters associated with SAGD, require membranes that can accommodate higher temperatures up to 60 C. Other produced waters may allow for treatment at ambient temperatures but their higher salinities above 60,000 mg/l TDS require RO membrane to overcome high osmotic pressures and operate at feed pressures up to 1800 psi.\u0000 In recent years, membrane manufacturers have enhanced their exiting RO elements to address the challenges associated with the treatment of unique industrial streams such as produced water. Specifically, new, more robust element construction allow designers to push beyond the normal limits of temperature and pressure. One such element allows for operation at temperatures up to 90 C while a second, ultra high-pressure RO (UHPRO), can concentrate the total dissolved salts (TDS) up to 120,000 ppm (12%) while operating at pressures up to 1,800 psi (124 bar).\u0000 These unique elements can be used to increase the overall efficiency of the treatment facility by reducing the cost of brine disposal and maximizing water recovery. This paper will show how these new elements perform when operated beyond conventional pressure and temperature limits - including how individual ion passage and water permeability are affected at extreme conditions. This paper will share element performance data from laboratory and pilot studies. The data will be used as a basis for new designs at the extreme conditions associated with produced water treatment.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115067867","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 Generalized Dynamic Transfer Function for Ultra-Tight Dual-Porosity Systems","authors":"Jingzhe Zhang, M. Raslan, Cheng Wu, K. Jessen","doi":"10.2118/209324-ms","DOIUrl":"https://doi.org/10.2118/209324-ms","url":null,"abstract":"\u0000 The Warren and Root (1963) transfer function laid the foundation for describing the mass transfer between the matrix and fracture blocks in dual-porosity (DP) reservoir simulation. However, the pseudo steady-state (PSS) assumption imbedded in the approach of Warren and Root is no longer applicable when the duration of the transient state is prominent (tight oil or shale gas reservoirs). Lim and Aziz (1995) derived new shape factors in a framework that avoids the PSS assumption. However, similar to the formulation of Warren and Root, the approximation of Lim and Aziz fails to capture the pressure gradients inside matrix blocks for tight rocks with substantial characteristic times for mass transfer.\u0000 In this paper, we introduce a generalized dynamic transfer function that can accurately predict the pressure response of ultra-tight DP formations. Based on the Vermeulen (1953) approximate solution, we first derive the new transfer function to model fluid flow for one, two, and three sets of perpendicular fractures where the matrix blocks are approximated by planar, cylindrical, and spherical geometries, respectively. Then, we apply it for rocks with anisotropic permeability. We extend our transfer function to represent more realistic geology by considering irregular-shaped matrix blocks. The proposed transfer function accounts for physical mechanisms at play in the reservoir and is applicable to describe different diffusion-type processes.\u0000 Development and testing of the dynamic transfer function were done in the open-source environment of the MATLAB Reservoir Simulation Toolbox (MRST). The implementation was validated using single-block DP calculations and fine grid single-porosity (SP) models. We report results from several examples covering a broad range of reservoir parameters. For comparison purposes, we also report the simulation results from a traditional transfer function, incorporating Lim and Aziz shape factors, in MRST and commercial simulators (CMG and ECLIPSE). We demonstrate that our proposed dynamic transfer function accurately predicts the pressure response across early and late times, while the traditional transfer function with Lim and Aziz shape factors can depart substantially from the true solution for ultra-tight DP reservoirs.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121373621","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":"Parameterization of Petrophysical and Geomechanical Properties Alteration in Sandstone Formations by Water-Based Drilling Fluids","authors":"F. Civan","doi":"10.2118/209248-ms","DOIUrl":"https://doi.org/10.2118/209248-ms","url":null,"abstract":"\u0000 The alteration of the petrophysical and geomechanical properties of sandstone formations by exposure to barite-weighted water-based drilling mud is described by a physically based kinetics model satisfying the low-end and high-end limit values. This model leads to a modified power-law equation for variation of various properties of porous rocks as a function of time. The variations of the porosity, permeability, unconfined compressive strength, tensile strength, Young's modulus, Poisson's ratio, bulk modulus, rigidity or shear modulus, uniaxial compaction or oedometer modulus, and Lamé's parameter of Buff Berea sandstone core samples by exposure time to water-based drilling fluids are described accurately by the modified power-law equation.\u0000 The application of the modified power-law equation leads to more accurate and proper correlations of the experimental data of the petrophysical and geomechanical properties alterations of sandstone in a physically meaningful manner. Further, the conditions and limitations of the previous correlations are investigated and compared with the new improved correlations developed using the modified power-law equation. The previous correlations predict unrealistic end-point values, such as plus or minus infinity for the initial and the final long-time limit conditions, and therefore they are valid only for applications in the range of the experimental data. The modified power-law equation circumvents the shortcomings of the previous correlations conveniently.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"71 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121467298","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 Comprehensive Review of Tracer Test Applications in Geothermal Reservoirs","authors":"Hakki Aydin, N. Nagabandi, Diyar Jamal, C. Temizel","doi":"10.2118/209325-ms","DOIUrl":"https://doi.org/10.2118/209325-ms","url":null,"abstract":"\u0000 Tracer test is a strong tool that is used to understand the connectivity between injection and production wells in geothermal reservoirs. It is essential to design and implement a tracer test for particular reservoir properties. Inappropriate tracer tests, might cuase wrong reservoir characterization interpretations. This study incorporates in the design, the implementation, and the interpretation of tracer tests in geothermal reservoirs. This study is populated with numerous field applications to ensure better understanding of the subject.\u0000 The study initially present the types of tracers used in geothermal reservoirs. The appropriate tracer type is selected based on various parameters such as reservoir conditions, economics, type of measurement devices available, minimum detection concentration, environmentally friendly, and stability at reservoir conditions. Once the type of tracer is selected, the amount of tracer to be injected and the tracer sampling frequency are determined based on the distance between wells, mean traveling time, and the desired peak concentration. The tracer is injected as slug/continuous type to the selected injection wells and sampling from production wells. The measured tracer concentrations are then modeled with analytical methods such as the multi-fractures, single fracture, dual-porosity, and homogenous models.\u0000 Naphthalene sulfonates, is frequently used in high-temperature geothermal reservoirs because of is high resistance and half-life in harsh conditions. Salts such as sodium chloride and potassium chloride are also conservative in harsh conditions; however, a large amount of salt is required to be injected to create an additional concentration in the reservoir brine, which already includes a certain salt concentration. Fluorescein is mostly applicable in low enthalpy reservoirs because of its weakness at high temperatures. Analytical models are matched with field data by using the nonlinear least square method. The most representative reservoir model is determined by evaluating the sum of the squared differences between tracer concentrations of the model and field data. Geothermal reservoirs are generally best matched with multi-fractures and dual-porosity models because of the secondary permeability and porosity of tectonic activities and mineral dissolution mechanisms.\u0000 This study, provides a detailed information about tracer test design, implementation, and interpretation. It serves as a guidance by including numerous field cases and the latest research about tracers in geothermal.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114709658","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":"Evaluation of Stresses Alteration on the Productivity of Marcellus Shale Horizontal Well","authors":"Mohamed El Sgher, K. Aminian, S. Ameri","doi":"10.2118/209303-ms","DOIUrl":"https://doi.org/10.2118/209303-ms","url":null,"abstract":"\u0000 The objective of this study was to investigate the impact of fracture properties and mechanical rock properties on stress changes and, consequently, the productivity of a horizontal Marcellus Shale well with multi-stage fractures.\u0000 The available advanced technical information from the Marcellus Shale horizontal wells at MSEEL site provides an opportunity for an integrated analysis to gain insight into the impact of stresses changes. When the pore pressure decreases due to depletion in a reservoir, the increase in effective stress results in a reduction in fissure permeability and porosity that affects cumulative gas production. In this study, the Mohr-Coulomb model, the foremost common model, was utilized to account for geomechanical effects.\u0000 A reservoir model which incorporated the gas storage mechanisms inherent in shales, i.e., matrix porosity, natural fracture porosity, and adsorption was developed. The mechanical properties of the shale were estimated from the available well log data. The core, log, completion, stimulation, and production data from the wells located at the Marcellus Shale Energy and Environment Laboratory (MSEEL) were utilized to obtain the formation and completion properties for the model. Barton Bandis Model was then implemented in the reservoir model to investigate the closure of the natural fractures during production. The impact of the stress changes was then investigated by performing parametric studies.\u0000 The geomechanical effects such as compaction and subsidence increase as the length of the hydraulic fracture increases. Furthermore, the higher the initial hydraulic fracture conductivity is, the more significant geomechanical effects become. Both of these are the results of greater pressure depletion. Additionally, as the pressure drawdown increases (wellbore pressure decreases), geomechanical effects increase. Mechanical rock properties (Young's modulus and Poisson's ratio) also influence the geomechanical effects. As Young's modulus of the rocks decreases, cumulative gas production increases due to compaction drive.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122209817","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":"Analyzing X-Ray CT Images from Unconventional Reservoirs Using Deep Generative Models","authors":"Yulman Perez Claro, N. Dal Santo, Vignesh Krishnan, A. Kovscek","doi":"10.2118/209280-ms","DOIUrl":"https://doi.org/10.2118/209280-ms","url":null,"abstract":"\u0000 Characterization of rock samples is relevant to hydrocarbon production, geothermal energy, hydrogen storage, waste storage, and carbon sequestration. Image resolution plays a key role in both property estimation and image analysis. However, poor resolution may lead to underestimation of rock properties such as porosity and permeability. Therefore, improving the image resolution is paramount. This study shows the workflow for 2D image super-resolution processes using a Convolutional Neural Network (CNN) method. The rock samples used to test the networks were three unfractured Wolfcamp shales, a Bentheimer sandstone (Guan et al., 2019), and a Vaca Muerta (Frouté et al., 2020) shale. These samples were imaged with a clinical Computed Tomography (CT) scanner (100's µm resolution) as well a microCT scanner (10's µm resolution). This established training, validation, and test data sets. The deep learning architectures were implemented in Matlab 2021b. The network performance is calculated using two metrics: i) pixel signal to noise ratio (PSNR) and ii) structural similarity index method (SSIM). In addition, porosity values on the image data sets are presented to illustrate their relevance. Training options and different strategies for network tuning are also discussed in the results section. Results illustrate the potential for AI to improve the resolution of CT images by at least a factor of 4. This level of improvement is essential for resolving fractures, other permeable conduits in impermeable shale samples, and shale fabric features. We outline a pathway to greater improvement of resolution.","PeriodicalId":224766,"journal":{"name":"Day 2 Wed, April 27, 2022","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132120286","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}