Day 3 Wed, September 26, 2018最新文献

{"title":"Smart Fluid Processing at Reduced Footprint – Separation Redefined","authors":"Catherine Manion, Sheldon McCrackin, Joshi Mahendra, Paul Wang, S. Pal","doi":"10.2118/191620-MS","DOIUrl":"https://doi.org/10.2118/191620-MS","url":null,"abstract":"\u0000 Efficient processing of fluids from flowing wells is an important function on a topside facility to maintain optimum hydrocarbon production. Many oil and gas facilities face the additional challenge of limited available footprints to process additional capacity. Normally, onshore facilities move process fluids from the wellhead to a de-sander unit, and then to a 2-phase or 3-phase separator unit. In offshore and onshore production facilities, fluids from multiple wells are sometimes co-mingled in a manifold and processed through two or three separation stages with progressively lower pressures to separate gas, crude oil, and produced water. Sequential pressure letdown and numerous fluid pump-around loops to separator vessels and interconnected piping with pumps, valves, and instrumentation occupy a large space on a wellsite. To add processing flexibility in an ever-changing fluid composition (water cut, gas vapor fraction (GVF), and solids loading) from co-mingled production wells and to remove the bottleneck at the topside processing capacity, a chemically enhanced, smart compact separation system has been developed.\u0000 The new separation system is based on the centrifugal (CF) separation principle. After comprehensive laboratory testing and Computational Fluid Dynamics (CFD) model validation for separated fluid streams, the system was tested in field conditions at an unconventional wellsite to benchmark mechanical reliability, separation effectiveness, and robustness. The modular design concept of this new system enables operation at 200 to 10,000 bbl/d fluid capacity at nominal increments by adding units in parallel. The system is designed to handle 30 to 99% water cut and normally encountered solids or fines concentrations. This technology is also able to handle ever-changing fluid conditions at the well such as production decline or water cut changes by using a digital interface that controls the separator operation based on inlet fluid conditions. This smart, compact separation system enables efficient separation and reduces the need for over-sized separation vessels.\u0000 A 2,000 bbl/d, two-phase (oil/water) system has consistently achieved residual oil-in-water (OIW) levels below 400 ppm in the water outlet without chemical addition enhancement. The residence time for separation is less than a minute for the 2,000 bbl/d prototype unit, enabling it to be used as an alternative to a freewater knockout (FWKO) vessel. The prototype unit has a 4-in. diameter housing that is mounted on an 8-feet cast-iron frame with a 15-hp electrical motor coupled as the prime mover. The lab and long-term field test results have also indicated that the CFD simulations can effectively reveal the mechanism of oil-water separation as well as validation of separator sizing parameters for various flow capacities. The refined control algorithms are still in development phase, but when completed they will control the separator dynamically as flow conditions change in the","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128275590","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 Dynamic Model with Friction for Comprehensive Tubular Stress Analysis","authors":"R. Mitchell, A. McSpadden, M. Goodman, R. Trevisan, R. D. Watts, N. Zwarich","doi":"10.2118/191640-MS","DOIUrl":"https://doi.org/10.2118/191640-MS","url":null,"abstract":"\u0000 A new model technique is described for comprehensive dynamic stress and displacement analysis of wellbore tubulars including friction loads. A dynamic model of tubing forces is necessary to predict local pipe velocity which in turn determines the magnitude and direction of localized frictional contact. By tracking dynamic changes in axial force starting from the initial running state, a complete load history may be simulated through the life of the well.\u0000 The dynamic friction model subdivides the string joint by joint and uses an elastic pipe momentum balance. Pipe velocity is related to axial force by the elasticity equation. Dynamically determined velocity is necessary to predict magnitude and orientation of local node friction vectors. Damping for the dynamic analysis is provided by annular fluid viscosity. The elastic equations are solved as a set of algebraic equations in terms of past and future values of pipe axial force and velocity. Key model inputs such as pressure, temperature, fluid and wellbore friction coefficients can be changed at each successive load step.\u0000 Running loads and packer setting with slack-off or pick-up loads determine the initial string configuration. Given the initial configuration, each subsequent load case is calculated starting from the prior load and resultant friction state, allowing for full history dependence. The surface velocity profile of running individual stands is a key input. Unexpected magnitudes of downhole transfer of surface load are demonstrated. Change in operation load sequence is shown to produce significant differences in tubular axial loads, indicating that special attention to load history should be considered when performing tubular stress analysis. For slack-off, overpull, or packer setting events the model can track dynamic load response at downhole points such as a packer or cement top. An example well with deviated profile and planned sequence of life-cycle operations including stimulation, production and shut-in was simulated for a variety of load sequences. The model has been validated against field data using the actual hook load plot during installation of a single-trip, multi-zone intelligent completion in an offshore highly-deviated ERD well. Example calculations are given for an HPHT subsea well and a horizontal unconventional well.\u0000 The dynamic friction model allows for seamless integration of running loads with friction into a fully sequential stress analysis of subsequent well life-cycle loads for landed strings. Current industry models separate installation state from the in-service life envelope. From comparison with appropriate static analytic solutions and industry standard drag and stress models, dynamics were found to affect friction force directions and magnitudes, suggesting that tubular dynamics cannot be neglected.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128058375","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":"Determining Water Saturation in Permian Basin Intercalated Reservoirs Using NMR Log Data","authors":"Pedro A. Romero Rojas, M. Bacciarelli, P. Elkington, R. Shokeir, K. Newsham, J. Pumphrey, E. Lopez, M. Morys, D. Avdeev","doi":"10.2118/191587-MS","DOIUrl":"https://doi.org/10.2118/191587-MS","url":null,"abstract":"\u0000 Alternating conventional and unconventional reservoir layers in the Permian Basin challenge the acquisition, processing, and interpretation of water saturation (Sw) using nuclear magnetic resonance (NMR) log data. A new-generation NMR wireline tool addresses these challenges using a specially designed conventional-unconventional activation sequence to enable construction of optimized maps of Longitudinal–Transversal Relaxation times (T1-T2 maps) at regular depth intervals.\u0000 T1-T2 maps are used to compute level-by-level Sw based on a multicomponent fluid model with appropriate statistical properties. Each spot in the T1-T2 space represents a fluid component from which a volume fraction is calculated. Integrating the volume fractions gives the total porosity. Because of the diverse relaxation mechanisms in the conventional and unconventional layers, oil spot positions with T1/T2 values greater than two reflect either viscosity (for bulk relaxation) or pore-size distribution (for surface/volume relaxation). Water tends to be close to the 1:1 T1/T2 diagonal line with T1/T2 values less than two. Low permeability means that mud-filtrate invasion does not appear on the T1-T2 maps.\u0000 NMR porosity matched expected values based on core and density-neutron log analysis. NMR fluid-typing-derived Sw—including clay bound water (CBW), capillary bound water (BVI), and free water—matched values from tested intervals. Results are in good agreement with reference values from production and core data within an uncertainty of one standard deviation. The resolution of fluid components in intervals where the components overlap can be enhanced by changes in the inversion parameters and map-grid dimensions.\u0000 This methodology for conventional-unconventional data acquisition followed by a multimodel approach for fluid typing will be applied to other wells. It enables a more accurate assessment of water saturation, especially when intercalated layers of conventional and unconventional reservoirs are present.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128384080","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":"Estimating Gas Relative Permeability of Shales from Pore Size Distribution","authors":"B. Ghanbarian","doi":"10.2118/191878-MS","DOIUrl":"https://doi.org/10.2118/191878-MS","url":null,"abstract":"\u0000 Modeling shale gas relative permeability, krg, has numerous practical applictaions, particularly in gas exploration and production in unconventional reservoirs. krg is a key petrophysical quantity for accurately determining recovery factor and production rate. In the literature, a few theoretical models developed to estimate krg are based upon either a \"bundle of capillary tubes\" conceptual approach or a combination of universal scaling laws e.g., from percolation theory. The former is a severely distorted idealization of porous rocks, while the latter is, generally speaking, valid near the percolation threshold and/or in rocks with narrow pore-throat size distribution. Although the effective medium approximation has been successfully applied to model wetting- and nonwetting-phase relative permeabilities in conventional rocks, to the best of the author's knowledge, it has never been used to estimate krg in unconventional reservoirs. Therefore, the main objective of this study is to develop a theoretical model based on the effective-medium approximation, an upscaling technique from statistical physics, to estimate shale gas relative permeability from pore-throat size distribution. In this study, we presumed that pore-throat sizes conform to a truncated log-normal probability density function. We further presumed that gas flow under variably-saturated conditions is mainly controlled by two mechanisms contributing in parallel: (1) molecular flow and (2) hydraulic flow. The total conductance of a single pore (gt), therefore, was equal to the summation of the molecular flow conductance, gm, and the hydraulic flow conductance, gh (i.e., gt = gm + gh). We then invoked the governing equation from the effective-medium approximation to determine effective conductances and, accordingly, gas relative permeabilities at various saturations. Results showed that krg varies as the log-normal distribution parameters standard deviation (σ) and geometric mean pore radius (rm) alter. By comparison with two- and three-dimensional pore-network model simulations, we found that the proposed model estimated gas relative permeability accurately, particularly in three dimensions. We also estimated krg from the pore-throat size distribution derived from measured mercury intrusion capillary pressure (MICP) curve for three experiments (i.e., Eagle Ford, Pierre, and Barnnet) and found that krg of Barnnet was remarkably less than that of Pierre and Eagle Ford.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"33 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126388435","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":"Collaborative Real-Time Analysis to Reduce Non-Productive Time","authors":"Garrett C. Guidry, Kyle Spezia, G. Salmon","doi":"10.2118/191631-MS","DOIUrl":"https://doi.org/10.2118/191631-MS","url":null,"abstract":"\u0000 Operators often use real-time operation centers (RTOC) as a funnel point for data streams transmitted from multiple rigs during the well construction process. A RTOC is typically staffed by subject matter experts (SMEs), with the primary goals of interpreting real-time wellbore conditions and relaying actionable recommendations to help reduce nonproductive time (NPT) and well control incidents.\u0000 Automation is a strong industry trend. Autonomous systems are being developed to flag potential NPT events before they occur; however, these systems are not yet widely used. In the absence of these systems, workflows among complementary disciplines have been developed to identify potential NPT events in large data streams transmitted to a RTOC. This paper presents example scenarios from deepwater prospects with potential actionable recommendations.\u0000 Robust data streams transmitted to a RTOC can be received by the overlapping disciplines of hydraulics optimization, drilling optimization, and geomechanics. Staff from each discipline filter through the raw data to capture incoming information relevant to their respective output analysis. A key goal of each discipline is to mitigate the risk of NPT through real-time identification of warning trends observed during deepwater drilling in narrow pressure window situations. The multidisciplinary overlapping efforts produce a process that is much more effective than is possible with each discipline operating independently. Because real-time geomechanics seeks to update the bounding conditions of the downhole pressure operating windows, collaborative workflows are structured around validation and calibration of the real-time geomechanical model.\u0000 Collaborative workflows are presented for specific operations during the well construction process in which NPT events are likely to occur, such as tripping out of the hole and drilling. In the examples, real-time calculated equivalent circulating density (ECD) models, hole cleaning parameters, swab pressure models, and torque/drag plots provide input to the real-time geomechanical model. Outputs of this analysis are actionable recommendations, such as an extended flow check, check trip, or mud weight increase. The workflows were developed based on lessons learned from information in a central database and the resulting best practices from multiple deepwater wells.\u0000 Decision makers are provided with data-supported recommendations at crucial junctures; these recommendations typically involve costly rig time. The trade-off between increased rig time and benefits gained from the recommendation is difficult to quantify. The workflows derived from a library of NPT events address the perception of wasted rig time and provide context to real-time interpretations. Combined plots supporting the recommendation provide confidence for the driller that the increased rig time is time justified.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127303900","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":"Capping Stack Technology Comes of Age","authors":"A. Cuthbert","doi":"10.2118/191687-MS","DOIUrl":"https://doi.org/10.2118/191687-MS","url":null,"abstract":"\u0000 While several years have passed since the 2010 Gulf of Mexico (GOM) source control incident that caused a six-month drilling moratorium, the industry likely believes it is fully prepared to prevent or mitigate the effects of a similar incident in a timely manner. However, installing a source control device on a blowing well is a technically complex exercise, one that has never been performed; while performing such an operation, one should consider challenges posed by metocean conditions, coupled multiphase hydrodynamics, and multibody interactions that complicate the deployment and docking of a capping stack onto a subsea wellhead.\u0000 The latest gate-valve technology intended to close against flow presents a more compact option for rapid capping than unwieldy ram-based systems. The speed of deployment of the lighter capping stack is attributed to the availability of suitable aircraft, lifting equipment at the airport or dockside, and an ample supply of suitable deployment vessels. The underlying logistical issues that prevent rapid responses to subsea incidents have not, for the most part, been addressed until now. A development differentia in capping-stack technology has been necessary to exact the speed of response that the industry calls for and to meet the expectations of stakeholders and the general public. Fortunately, the industry now has access to technology that can be deployed to a source control incident in any global location in a matter of days.\u0000 Sophisticated, high-fidelity simulation, hitherto unavailable, incorporates metocean sea state and uses coupled multiphase hydrodynamics and multibody interaction effects of vessel motion, suspension system dynamics, and the hydrodynamics of the capping system within the unstable blowout forces to create an accurate analysis that addresses plume and landing-force analysis at the wellhead. Coupled with the tools to accurately simulate the effects of the force dynamics from surface to wellhead to complete the entire process, the advances accompany the new capping design and enhance the ability to determine landing capability, heralding further advancement in source control technology and techniques.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122755810","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 Formation Evaluation of Organic-Rich Shale Formations by Integrating Digital Rock Analysis with Core Data and Well Logs","authors":"Yong He, Liwei Jiang, L. Chi, X. Wang, Qiang Chen, S. Roth, Hu Dong","doi":"10.2118/191674-MS","DOIUrl":"https://doi.org/10.2118/191674-MS","url":null,"abstract":"\u0000 To reliably evaluate the petrophysical, geochemical, and geomechanical properties of an organic-rich shale formation in China, we integrated digital rock analysis (DRA) with conventional core data and well log interpretation. The objectives of this paper included (a) to create a complete and accurate formation evaluation model for Wufeng-Longmaxi shale gas formation by combining pore-scale (digital rock), core-scale, and log-scale data; (b) to accurately characterize the micro-scale pore space, rock matrix, and organic matters in this formation, and create 3D pore network models from core samples; and (c) to identify the geological and engineering sweet-spot along vertical wellbore.\u0000 For well log interpretation, we obtained Gamma Ray (GR), spectral GR, neutron, density, resistivity, sonic logs, and elemental spectroscopy logs in the wells. For core measurements, we performed static and dynamic geomechanical experiments on core samples. For DRA, we obtained multi-scale images of the organic-rich shale samples, using three-dimensional (3D) micro-Computed Tomography (CT), 3D Focused-Ion-Beam Scanning Electron Microscope (FIB-SEM), and high-resolution Back-scattered Electron (BSE) imaging. Mineralogical and elemental analysis was also obtained by QEMSCAN. We then quantified various petrophysical properties from the digital rocks, including organic/inorganic porosity, Total Organic Carbon (TOC), elemental concentration and mineralogy. Most of the obtained properties were cross-validated with log data. Furthermore, we extracted pore network models from the digital rocks to quantify pore connectivity, pore throat size distribution, organic pore radius distribution, … etc, to provide more micro-scale information within the rock. Next, we determined the origin of quartz and the cause of high natural gamma-ray sections in the formation, based on point-by-point elemental analysis on SEM images and geochemical analysis. At last, we investigated various geomechanical properties using digital rock, core and log data. We compared geomechanical properties from core experiments and logs, then performed sensitivity study by DRA.\u0000 Two vertical wells in Wufeng-Longmaxi shale formation were studied by the introduced workflow. The DRA, core, and log data were mostly in good agreement, confirming the reliability of these methods. When multiple logs showed discrepancies in TOC, DRA provided additional key information for judgment. Based on the obtained petrophysical, geochemical, and geomechanical properties, we accurately characterized the Wufeng-Longmaxi formation, predicted the shale gas sweet-spot along the wellbore, and provided suggestions for future operations of horizontal drilling and fracking in this formation.\u0000 The exploration and development of shale gas formations in China attracted extensive interests among Chinese national oil companies and international operators. However, it was extremely challenging due to the complex geological features of organic-r","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"104 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127626935","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 Novel X-Ray Based High Pressure Mass Flow Rate Sensor for MPD Operations","authors":"Vivek Singhal, P. Ashok, E. Oort, Paul Park","doi":"10.2118/191595-MS","DOIUrl":"https://doi.org/10.2118/191595-MS","url":null,"abstract":"\u0000 Managed Pressure Drilling (MPD) allows one to drill through formations with narrow pressure windows, thereby making those formations that cannot be drilled with conventional techniques accessible. It also provides the capability for early detection and safer handling of well control events. This technique requires accurate estimation of the annular pressure profile and the delta mass flow rate. These measurements can be improved through accurate density and mass flow rate measurement at the high pressure (7500 psi) input side of the well. Since no good metering technologies exist to make these measurements, the objective was to develop a high pressure density and mass flow rate sensor.\u0000 A comprehensive review of all existing flow rate and density measurement instruments suggested that an X-ray based sensor was the best option for the high pressure fluid line. Multiple experiments were conducted to determine the electrical power range (voltage and power) for the X-ray tube that would work best for mud between densities in the range of 8 to 20 ppg. Experiments were then conducted to test the accuracy and feasibility of techniques developed for density and volumetric flow rate measurement. Based on these experiments, an X-ray source and detector were identified and a sensor was designed for inline use on 4 inch pipes. Two approaches were developed to estimate density using the sensor. The first was an empirical approach where sensor gray level values were directly mapped onto mud density values though in laboratory experiments. These mappings can then be used in the field to estimate density. The second was a model-based approach that estimates density based on the Beer Lambert's law. Both these approaches were tested experimentally using drilling muds of different densities and compositions.\u0000 A mechanism that uses X-rays to determine volumetric flow rate was also designed and tested using both simulations and experiments. A real-time calibration subsystem had to be added to the sensor to preserve measurement accuracy and precision over time. Based on encouraging results from simulations and experiments, a laboratory prototype was built and is currently undergoing flow loop tests. This is the first time an X-ray mass flow rate measurement sensor has been designed to be used on high pressure lines. Preliminary findings indicate that no existing sensors used for similar applications can match the measurement accuracy and frequency that may be offered by this technology. Development of this sensor would improve the safe drilling of complex wells with narrow drilling windows.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"101 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114330126","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":"Existence and Prediction of Severe Slugging in Toe-Down Horizontal Wells","authors":"J. Nair, E. Pereyra, C. Sarica","doi":"10.2118/191611-MS","DOIUrl":"https://doi.org/10.2118/191611-MS","url":null,"abstract":"\u0000 Severe slugging is an important flow assurance issue, typically observed in offshore pipeline-riser systems. The consequences of severe slugging include flooding of downstream production facilities and an overall decrease in productivity. It had been previously thought that severe slugging would be limited to systems with a downward inclined pipeline and vertical, catenary or lazy-S shaped riser. This paper presents the results of an experimental and modeling study, which demonstrates the existence of severe slugging in systems with upward inclined lateral flow paths such as a toe-down well.\u0000 The severe slugging phenomena described in this paper was observed in a large scale experimental facility constructed for the purpose of studying flow behavior in horizontal wells. The facility enabled the study of the effect of the completion parameters like end of tubing location and the presence of a packer. Various gas and liquid rates were tested in the facility, and slug flow was the dominant flow pattern in the lateral section. The facility was also designed to test gas lift performance in horizontal wells. Therefore, the effect of gas lift on the severe slugging phenomenon was also studied.\u0000 Based on the experimental observations, two severe slugging prediction models were developed. The first was a transient model based on the Balino et al. (2010) model. The second was a single point criterion based on the Bøe (1981) criterion. The constitutive equations and modeling results are also presented in this paper.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115160832","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":"Smart Oilfield Safety Net - An Intelligent System for Integrated Asset Integrity Management","authors":"Muhammad Rizwan Saeed, C. Chelmis, V. Prasanna","doi":"10.2118/191718-MS","DOIUrl":"https://doi.org/10.2118/191718-MS","url":null,"abstract":"\u0000 In smart oilfields, a large volume of data is being generated related to assets, personnel, environment, and other production and business-related processes on a daily basis. Storing vast amounts of data is only justifiable if it leads to the discovery of actionable insights which can then be translated into improvements in operational efficiency and Health, Environment, and Safety (HES) conditions. Smart oilfield data is of high volume, variety, and velocity and can be located in multiple data silos. This presents an urgent need to develop scalable and extensible techniques that can enable domain experts to access data and perform analytics to yield better decisions and results. The focus of this paper is on the process of Asset Integrity Management and the role of Semantic Web technologies for significantly improving decision-making in this domain. The most significant challenges, thus, are to manage the high volumes of data, create a holistic view of asset integrity data, allow intuitive access to the data, and generate insights through an agile system that can be utilized by domain experts without requiring extensive assistance from IT experts. For this, we present the Smart Oil Field Safety Net (SOSNet) system, a Semantic Web-driven platform, that performs integration of asset integrity data, provides simplified querying mechanism for accessing the integrated data and facilitates analytics on top of it to improve efficiency and robustness of the process of Asset Integrity Management.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128157053","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}