Volume 11: Petroleum Technology最新文献

{"title":"Rig-Assisted Snubbing: Drillpipe Pressure Control in MPD/UBD","authors":"J. Aasen, J. Svensson","doi":"10.1115/omae2020-18168","DOIUrl":"https://doi.org/10.1115/omae2020-18168","url":null,"abstract":"\u0000 An important pressure control issue during live well work is the expulsion force acting on the drillpipe. Wellhead pressure multiplied by drillpipe sealing area in the blowout preventor must be overcome before entering the well. The highest snubbing force (compression) is applied when running the first joint into the well since pipe weight is at its lowest at this time. Focus of this paper is the mechanical analysis of the drillpipe as a well barrier element during live well entry. We look at normal operation (primary well barrier) and contingency (secondary well barrier). Load cases include critical unsupported buckling, helical buckling inside tubing guide, collapse and burst. In critical unsupported buckling there is no radial confinement of the pipe and the critical buckling limit is determined at the onset of lateral deflection. On the other hand, inside the tubing guide the pipe is allowed to buckle into a helix and the buckling limit is related to permanent corkscrewing of the pipe.\u0000 Technical contributions in this paper include engineering design formulas for unsupported buckling and helical buckling. Also presented are experimental buckling results from pipe up to 3½ inch (8.9 cm) diameter. Design calculations for primary and secondary well barriers are explained and analyzed using a field case. All load calculations are based on zero neutral axial stress as stress reference datum, which produces a yield circle that is conveniently deployed for three-dimensional well tubular design. The use of the dimensionless yield circle is found to be an efficient method to assess helical buckling loading and the combined effects of pressure and axial stresses.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"317 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133733293","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":"Wear-Factor Prediction Based on Data-Driven Inversion Technique for Casing Wear Estimation","authors":"K. MittalManish, Robello Samuel, Aldofo Gonzales","doi":"10.1115/omae2020-19035","DOIUrl":"https://doi.org/10.1115/omae2020-19035","url":null,"abstract":"\u0000 Wear factor is an important parameter for estimating casing wear, yet the industry lacks a sufficient data-driven wear-factor prediction model based on previous data. Inversion technique is a data-driven method for evaluating model parameters for a setting wherein the input and output values for the physical model/equation are known. For this case, the physical equation to calculate wear volume has wear factor, side force, RPM, tool-joint diameter, and time for a particular operation (i.e., rotating on bottom, rotating off bottom, sliding, back reaming, etc.) as inputs. Except for wear factor, these values are either available or can be calculated using another physical model (wear-volume output is available from the drilling log). Wear factor is considered the model parameter and is estimated using the inversion technique method. The preceding analysis was performed using soft-string and stiff-string models for side-force calculations and by considering linear and nonlinear wear-factor models. An iterative approach was necessary for the nonlinear wear-factor model because of its complexity. Log data provide the remaining thickness of the casing, which was converted into wear volume using standard geometric calculations.\u0000 A paper [1] was presented in OMC 2019 discussing a method for bridging the gap. A study was conducted in this paper for a real well based on the new method, and successful results were discussed. The current paper extends that study to another real well casing wear prediction with this novel approach. Some methods discussed are already included in the mentioned paper.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123189512","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":"Computational Fluid Dynamics Simulation of the Transient Behavior of Liquid Loading in Gas Wells","authors":"M. Khaled, M. A. Rahman, Ibrahim Hassan, Rasel A. Sultan, R. Hasan","doi":"10.1115/omae2020-18220","DOIUrl":"https://doi.org/10.1115/omae2020-18220","url":null,"abstract":"\u0000 Liquid loading is one of the major flow assurance challenges in gas wells, causing production problems and reducing the ultimate recovery. Liquid loading is defined as the inability of a well to carry all the co-produced liquid up the tubing. This leads to liquid accumulation in the well resulting in increased bottomhole pressure and decline of gas flow rate. Although many studies have been performed on liquid loading phenomena, available models generally lack the ability to capture transient behavior of liquid loading in gas wells. We have developed a computational fluid dynamics (CFD) model using Ansys Fluent 19.1 R3 version to model the transient features of liquid loading.\u0000 In this study, the CFD model is developed and validated with data from 42 meter long vertical pipe lab at Texas A&M University. The Eulerian multiphase approach combined with volume of fluid approach (VOF) - Multi-fluid VOF model with realizable k-Є turbulence closure is used to study the flow behavior. In addition, hexahedral mesh is utilized and compared to tetrahedron mesh to test accuracy and computational time.\u0000 The developed CFD model has unique parameters combinations that shows an acceptable agreement with the experimental work. Model accuracy and computational time is improved by using hexahedral mesh. Liquid film flow reversal mechanism is expected to be the root cause of liquid loading in gas wells rather than droplet fall back mechanism. The CFD model captures the transition from one phase to another that is crucial for determining well end life. Model novelty is based on the ability to be a reliable predictive tool that can help in the remediation of liquid loading and give a precise representation of liquid loading transient behavior in gas wells.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123306658","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 Study of Drill Cuttings Transport in Horizontal Well With Newtonian Fluid","authors":"Mohammad Mojammel Huque, S. Imtiaz, S. Butt, S. Zendehboudi, M. A. Rahman","doi":"10.1115/omae2020-18751","DOIUrl":"https://doi.org/10.1115/omae2020-18751","url":null,"abstract":"\u0000 Transport of cuttings is crucial in a horizontal drilling operation. Effective removal of cuttings is necessary for efficient drilling. An experimental investigation has been carried out to analyze the flow behaviour of solid cuttings in different drilling environments with visualization techniques.\u0000 This study investigates the cuttings transport mechanism in a horizontal annulus section. A 6.16 m long and 4.5″ × 2.5″ annulus section was used to model the real-time drilling behaviour with different flow rates, drill pipe rotations and eccentric positions. Water as a Newtonian fluid was used as drilling mud and 2–3 mm solid glass beds were used to simulate the drill cuttings. The in-situ volume fraction of cuttings in the annulus was estimated by Electrical Resistivity Tomography (ERT) analyzer. Visualization technique used to estimate the moving bed velocity in the horizontal annulus section. A highspeed camera was used to capture the transport phenomena of the moving solid particle at 2000 frames per second. The highspeed camera can effectively track each particle in the system. Analysis of high-speed camera revealed different cuttings transport phenomena like rolling of cuttings, stationary cuttings bed and cuttings suspended into the drilling mud.\u0000 Experimental investigation revealed that drill pipe rotation helps in cuttings bed movement and resist the formation of large cuttings dune in the annulus formation. Also, this study revealed that eccentric annulus shows less annular solid volume compared to a concentric annulus; however, an eccentric annulus is harder to clean compared to a concentric annulus section.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"79 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129262679","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":"Pressure Testing of Barrier Integrity","authors":"A. Raaen, E. Fjær","doi":"10.1115/omae2020-18713","DOIUrl":"https://doi.org/10.1115/omae2020-18713","url":null,"abstract":"\u0000 Plug and abandonment of a well is expected to ensure that the sealing integrity of the cap rock is restored. This also implies that the annulus between casing and rock is sealed off. Some formations may under the right conditions close in on the casing, providing a highly valuable contribution to the sealing. Although acoustic tools may be used to evaluate whether there is casing contact, the hydraulic integrity of such a barrier must be established by field testing for all potential formations.\u0000 While the main focus here is on natural shale barriers, the analysis and conclusions apply equally well to testing of cement based and other barriers.\u0000 This paper discusses two pressure integrity tests that are used for this purpose, the XLOT-type test and the communications test. The test procedures are outlined, and the expected sensitivity is estimated. In particular, it is shown that temperature effects may complicate test interpretation, possibly giving both false acceptance and false rejections of tests. Hence, it is of vital importance to include temperature measurements in the evaluation of the tests.\u0000 It is estimated that the leakage detection limit of both tests is significantly higher than the target value needed to ensure that sealing integrity has been restored. This calls for improvements of the testing procedures.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"64 1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122387761","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":"Statistical Determination of Bit-Rock Interaction and Drill String Mechanics for Automatic Drilling Optimization","authors":"A. Ambrus, B. Daireaux, L. Carlsen, Rodica Mihai, M. Balov, Ronny Bergerud","doi":"10.1115/omae2020-19191","DOIUrl":"https://doi.org/10.1115/omae2020-19191","url":null,"abstract":"\u0000 The ability to predict the response of a drill bit to the topside axial and rotational velocities of the drill-string is a prerequisite for any system aimed at automatically controlling the drilling parameters to optimize the rate of penetration and the overall quality of the well construction process. When drilling with a Polycrystalline Diamond Compact (PDC) bit, even the steady-state response can exhibit complex behavior, characterized by the presence of (at least) three different regimes whose range and parameters depend upon the bit characteristics and the mechanical properties of the formations being drilled. Transient effects significantly complicate the situation, especially when vibrations (axial, rotational or lateral) disturb the drilling process. Often, the root cause of these vibrations lies in the bit-rock interaction itself, while the drill string, through its elasticity and interaction with the borehole wall, may amplify or attenuate these vibrations. Therefore, continuous calibration of the drill string and bit-rock parameters from available surface and downhole measurements is critical for any automated control system relying on dynamic models of the drilling process.\u0000 We present a calibration procedure whose goal is two-fold: first, to identify the time-varying parameters involved in the bit-rock interaction, and second, to provide a low-order, transfer function model approximation of the drill string axial and rotational dynamics. Our approach is based on particle filter techniques and a refined instrumental variable method for transfer function model estimation, and allows for real-time estimation of the various model parameters. We illustrate its behavior against recorded drilling data, where the proposed methods are shown to capture the different dynamics in place. We explain, in addition, how the calibrated drill string and bit-rock interaction models can be integrated in a framework to identify drilling parameter regions prone to axial or rotational vibrations.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"54 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127391364","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":"Off-Bottom Plug Placement: How It Works?","authors":"A. Ghazal, I. Karimfazli","doi":"10.1115/omae2020-19344","DOIUrl":"https://doi.org/10.1115/omae2020-19344","url":null,"abstract":"\u0000 In Canada, the Alberta Energy Regulator’s (AER) liability report, issued in 2018, predicted that the number of inactive wells in the province will double by 2030. Despite the increase in the number of inactive wells, there is a need to close them properly to avoid hazards escape. Various aspects of well plug technologies in the Canadian abandoning industry are empirical. Many plugs are formed by injecting cement slurry into wells that are otherwise filled with fresh water for the slurry to build up on top of a water layer at a desired location. However, cement is heavier than water. Thus, successful plug placement following this methodology is questionable from the hydrodynamics perspective.\u0000 The present study aims to identify features of successful processes for placement of off-bottom plugs. To that end, we investigate mixing of fluids of different densities as the denser fluid is injected into the lighter fluid. Cement slurry is modeled as a viscoplastic fluid. The fluid motion is governed by hydrodynamic models, and the two fluids (i.e. cement and water) are considered to be miscible and are allowed to mix. Systematic numerical simulations aim to reveal how the characteristics of cement and the well configuration affect the placement process.\u0000 We show that successful plug placement depends on the formation of a mixed layer, of the wellbore fluid and cement slurry, below the injection site. We identify and provide representative cases of the processes promoting the formation of the mixed layer: high diffusion and growing instabilities.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128709223","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 Study of Laminar Displacement Flows in Narrow Horizontal Eccentric Annuli","authors":"A. Renteria, Yee Voon Liew, I. Frigaard","doi":"10.1115/omae2020-18219","DOIUrl":"https://doi.org/10.1115/omae2020-18219","url":null,"abstract":"\u0000 Wells with poor cement jobs are prone to develop paths where the hydrocarbons might leak to the surface. Such events cause environmental risks and costly repairs. Even though horizontal wells have been drilled since the 1980s, studies on the dynamics of the fluid-fluid displacement under this configuration are scarce.\u0000 In this work, we present experiments on the displacement of two Newtonian fluids in laminar regime in a horizontal uniform annulus. The minimum non-dimensional parameters required to describe the flow under such conditions include a buoyancy number (b), viscosity ratio (μ2/μ1) and eccentricity (e).\u0000 We have designed and built a flow loop that mimics the annular displacement under controlled and dimensionlessly comparable conditions found in field. Within this apparatus we can set key process parameters: flow rate, eccentricity, fluid rheology and density. Data acquisition is through imaging with high sensitivity cameras and partially automated instrumentation.\u0000 Preliminary results of the experiments show that there is a subtle balance between eccentricity and buoyancy. Sufficiently high values of |b| will end up in stratification of the fluids. The secondary flows created in an eccentric annulus compete against a positive buoyancy, driving the flow to the wide side (top) at moderate values of b. The effect of the viscosity ratio is most relevant at small values of b.\u0000 The experimental data from this work can be compared against both mathematical model predictions and computational simulations used in the design of primary cementing jobs.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124637651","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 Singular Value Decomposition (SVD) Enhanced Upscaling in Reservoir Simulation","authors":"Xu Zhou, M. Tyagi","doi":"10.1115/omae2020-19259","DOIUrl":"https://doi.org/10.1115/omae2020-19259","url":null,"abstract":"\u0000 Reservoir upscaling is an important step in reservoir modeling for converting highly detailed geological models to simulation grids. It substitutes a heterogeneous model that consists of high-resolution fine grid cells with a lower resolution reduced-dimension homogeneous model using averaging schemes. Its objective is to use a coarse grid model to represent a fine grid model, thus to reduce simulation time. The benefit of upscaling in reservoir simulation is that it efficiently saves simulation time, and effectively preserves key features of data for flow simulation.\u0000 Singular Vector Decomposition (SVD) is a matrix decomposition method. It has been used for image processing and compressing. It has been proved to be capable of providing a good compression ratio, and effectively saves digital image storage space. SVD also has been used in noise suppression and signal enhancement. It has been shown to be effective in reducing noise components arising from both the sound sampling and delivery system.\u0000 This study evaluates the effect of SVD in parameterization and upscaling for reservoir simulation. A two-phase flow reservoir model was created using data from the SPE tenth comparative solution project [1].\u0000 Simulation results show that SVD is valid in the parameterization of permeability values. The reconstructed permeability matrices using certain amount of singular values are good approximations of the original permeability values. Simulation results from SVD processed permeability values are similar to that using the original values.\u0000 SVD is then applied on the upscaled permeability value to evaluate the effectiveness on upscaling. Simulation results were compared between the base case, upscaled case, and SVD upscaled case. The simulation results did not show a significant improvement in the accuracy of predicting oil production by applying SVD on the upscaled permeability values. It could be because the reconstructed permeability matrix has the same dimension before and after the SVD processing, thus the model accuracy and efficiency are not significantly improved.\u0000 Future work includes adding more cases to further explore the effect of SVD on upscaling. The number of grid blocks may be increased, and more layers can be added to investigate whether SVD enhance upscaling for larger scale reservoir simulation models.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"73 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120958016","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 Flow Characteristics in an Oil-Water Separator Using Computational Fluid Dynamics","authors":"T. Potter, Tathagata Acharya","doi":"10.1115/omae2020-18939","DOIUrl":"https://doi.org/10.1115/omae2020-18939","url":null,"abstract":"\u0000 Multiphase separators on production platforms are among the first equipment through which well fluids flow. Based on functionality, multiphase separators can either be two-phase that separate oil from water, or three-phase that separate oil, natural gas, and water. Separator performances are often evaluated using mean residence time (MRT) of the hydrocarbon phase. MRT is defined as the amount of time a given phase stays inside the separator. On field, operators usually measure MRT as the ratio of active volume occupied by each phase to the phase volumetric flowrate. However, this method may involve significant errors as the oil-water interface height is obtained using level controllers and the volume occupied by each phase is calculated assuming the interface can be extrapolated from the weir back to the separator inlet. In this study, authors perform computational fluid dynamics (CFD) on a two-phase horizontal separator to evaluate MRT as a function of varying water volume flowrates (water-cut) in a mixture of water and oil. The authors use residence time distributions (RTD) to obtain MRT at each water-cut — a method that results in significantly more accurate results than the regular method used by operators. The numerical model is developed with commercial software package ANSYS Fluent. The code uses the Eulerian multiphase model along with the k-ε turbulence model. The simulation results show agreement with experiments performed by previous researchers. Additional simulations are performed to assess the effect of various separator internals on separator performance. Simulation results suggest that the model developed in this study can be used to predict performances of two-phase liquid-liquid separators with reasonable accuracy and will be useful towards their design to improve performances under various inlet flow conditions.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"61 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129682790","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}