Volume 11: Petroleum Technology最新文献

{"title":"Experimental Investigation of Pressure Drop of Gas/Non-Newtonian Flow in Horizontal Pipes","authors":"F. B. Rajeb, Mohamed Odan, S. Imtiaz, Yan Zhang, M. Awad, M. A. Rahman","doi":"10.1115/omae2020-18704","DOIUrl":"https://doi.org/10.1115/omae2020-18704","url":null,"abstract":"\u0000 Two-phase flow of gas/non-Newtonian fluid through pipes is commonly occurred in chemical industry and oil and gas refinery. Many correlations have been developed to evaluate pressure drop for non-Newtonian fluids. Based on that, these systems are not governed by Newtonian law of viscosity. However, only little experimental work has been devoted to study non-Newtonian flow behavior. In this present work, experimental setup has been conducted to investigate non-Newtonian two-phase (gas/ liquid) flow through pipes. Several concentrations of Xanthan Gum have been used as non-Newtonian liquid in the experiments and compressed air has been used as a gas. The flow rate and pressure of liquid and gas are changed by using a pump placed ahead of the mixing point. Pressure and temperature values are recorded by pressure sensors and thermocouples fixed at specific points along the pipe loop. Results of theses experiments are leaded to come up with experimental model for pressure drop of gas/non-Newtonian flow in pipes. Moreover, the flow regimes of two-phase gas/non-Newtonian flow at different conditions have been visualized through transparent tubes using a high-speed camera.","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":"129714323","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 on the Wall Factor for Rod-Shaped Proppant Settling in Vertical Fracture","authors":"Zhaopeng Zhu, Xianzhi Song, Xuezhe Yao, Shuo Zhu, Silin Jing","doi":"10.1115/omae2020-18824","DOIUrl":"https://doi.org/10.1115/omae2020-18824","url":null,"abstract":"\u0000 Hydraulic fracturing is an important technology to improve oil and gas production. In recent years, rod-shaped proppant has received increasing attention for its advantages in avoiding fracture closure and enhancing conductivity. Due to its special shape, the settling process in the fracture is more complicated than that of a spherical proppant. Accurate description of the wall factor of fracture on the settling rod-shaped proppant is pivotal in predicting the transport distance of rod-shaped proppant and improving the effect of fracturing. However, few researches have been reported about the fracture wall factor on the settling rod-shaped proppant. In this study, the transparent fracture model with different width and a high-speed camera were used to record the settling process of the rod-shaped proppant in the fracture. A total of 215 tests were carried out to analyze the effects of fluid properties, the equivalent dimensionless diameter, sphericity, and Reynolds number on the wall factor, involving the ranges of the equivalent dimensionless diameter and the particle Reynolds number are 0.03 to 1.47 and 0.03–1354.14, respectively. The settling processes of rod-shaped proppant under horizontal and vertical states were studied, and two wall factor models for the two states were established, respectively. The results show that the wall factor is a function of both the equivalent dimensionless diameter and Reynolds number. Finally, the prediction models of wall factor with the prediction error of 1.70 and 4.44% are established for these two Reynolds number regions, respectively. The results of this study can further improve the performance of rod-shaped proppant in hydraulic fracturing.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"25 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":"126570223","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":"Viscosity and Density Sweeps in Directional Wells","authors":"E. Ozbayoglu, F. Rodrigues, Reza Ettehadi, R. May, D. Clapper","doi":"10.1115/omae2020-18336","DOIUrl":"https://doi.org/10.1115/omae2020-18336","url":null,"abstract":"\u0000 As explorations advance and drilling techniques become more innovative, complex and challenging trajectories arise. In consequence, cuttings transport has continued to be a subject of interest because, if the drilled cuttings cannot be removed from the wellbore, drilling cannot proceed for long. Therefore, efficient cleaning of highly inclined and horizontal wellbores is still among the most important problems to solve, because these types of wells require specialized fluid formulations and/or specific hole cleaning techniques.\u0000 There are numerous studies and methods that focus in cuttings transportation in highly inclined and horizontal wells. One of them is the use of viscosity and density sweeps. Sweep pills have been used in the drilling industry as a tool to improve hole cleaning. This report presents the analysis of the performance of different sweeps pills working independently and in tandem in polymeric, oil and synthetic based systems and the comparison between them.\u0000 The main objective of this project is to provide experimental evidence on which types of fluids perform better under certain conditions by studying the effect of viscosity and density in the bed erosion process in highly inclined and horizontal wells. In order to achieve that, several fluid formulations were tested at different inclination angles (90, 75, 60 degrees) in the Small Indoor Flow Loop property of The University of Tulsa’s Drilling Research Projects. The results of the tests are presented in terms of volume of drilled cuttings removed from the test section and measured differential pressures. All the tests were conducted under atmospheric pressure and ambient temperature. Moreover, a 2-Layer model is used for estimating the erosion performance of sweeps for design purposes, and the model estimations are compared with experimental results.\u0000 From the experiments, it was identified that polymeric, oil and synthetic based muds with similar density and rheological properties eroded and transported the drilled cuttings similarly under similar test conditions. Furthermore, pumping the sweep pills in tandem demonstrated higher cuttings transport efficiency when compared with the sweep pills applied independently.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"10 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":"131636187","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":"Sequential Annular Fluid Expansion Analysis for Wellbore Completion Design","authors":"Zhengchun Liu, Robello Samuel, A. Gonzales, Yongfeng Kang","doi":"10.1115/omae2020-18851","DOIUrl":"https://doi.org/10.1115/omae2020-18851","url":null,"abstract":"\u0000 Annular fluid expansion analysis (AFEA) is a vital step when designing an oil/gas well or geothermal well. Traditionally, an AFEA is performed between a drilling operation (initial condition) and a production operation (final condition). However, well design engineers desire to perform an AFEA between any two operations. The objective of this work is to address that challenge.\u0000 Sequential AFEA refers to the procedure in which output data (e.g., fluid volume change) of one AFEA are used as input data for another AFEA; the underlying operations are “sequential”. As a result, an AFEA can be configured between any two operations, provided that the “initial condition” operation is before the “final condition” operation.\u0000 This two-pass AFEA model has been implemented in computer programs and has been integrated with a commercial software tool, including a wellbore thermal flow simulator and tubular stress analyzer. Offshore well examples were used to validate the model. Case study results indicate that a sequential AFEA is in good agreement with a traditional one-pass AFEA in terms of both forward and backward operation sequences.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"22 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":"115417471","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":"Study on Safety Operation Period Model of Deep Water Typhoon Avoidance Well Control Considering Rheological Characteristics of Drilling Fluid","authors":"Wenqiang Lou, Zhiyuan Wang, Kai Du, Jianbo Zhang, Youqiang Liao, Shaowei Pan, Baojiang Sun","doi":"10.1115/omae2020-18421","DOIUrl":"https://doi.org/10.1115/omae2020-18421","url":null,"abstract":"\u0000 During the period of avoiding typhoon in deep-water drilling, the gas intrusion in the wellbore brings higher risk to the well opening operation. It is very important to improve the accuracy of typhoon avoidance cycle prediction to improve the efficiency of drilling operation and reduce the risk of well control. According to the yield stress characteristics of drilling fluid, the gas migration experiment in the yield stress fluid is carried out in this paper. Based on the experimental results and stress analysis, a prediction model of bubble rising velocity suitable for the yield drilling fluid is established. Considering the rheological properties of drilling fluid and pore characteristics of formation, a prediction model of initial bubble size is established. Combined with the velocity prediction model and bubble size prediction model, the calculation method of typhoon avoidance period is proposed. Through the calculation and analysis, it is found that under the condition of low invasion rate, the formation porosity has little influence on the initial size of bubbles, and the yield stress value of drilling fluid has great influence on the initial size of bubbles. At the same time, the model in this paper makes up for the problem that the prediction value of safe typhoon avoidance period calculated by the previous model is large, and reduces the risk of well opening operation. According to our calculation results, the measures of injecting drilling fluid with low yield stress at the bottom of the well and injecting drilling fluid with high yield stress at the top are put forward, which can effectively increase the safe typhoon avoidance period.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"174 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":"123202617","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 on Conductivity of Regional Sand and its Field Application","authors":"Minghui Li, Fu-jian Zhou, Jin Wang, Liang Tianbo, Yuechun Wang, Lufeng Zhang","doi":"10.1115/omae2020-18035","DOIUrl":"https://doi.org/10.1115/omae2020-18035","url":null,"abstract":"\u0000 Hydraulic fracturing is the most commonly used stimulation method at present. The improvement effect and validity period mainly depend on the fracture conductivity. Carbo proppant is widely used worldwide for its excellent performance in increasing the conductivity of fracture support. The proppant used in the fracturing development of the Karamay oilfield in Xinjiang is also mainly Carbo proppant, but Karamay has abundant regional sand resources due to its special geographical location and geological conditions. Compared with the high cost and transportation cost of the Carbo proppant, the available regional sand becomes cheaper and reduces the development cost. According to the evaluation standard of flow conductivity of proppant in petroleum and natural gas industry, Firstly, the basic physical properties of the regional sand in Xinjiang were evaluated through the laboratory experiment system, and compared with the Carbo proppant. Secondly, the effect of sand placement concentration (8kg, 10kg, 16kg) and mesh number of proppant (30/50, 40/70) on regional sand conductivity was studied based on the conductivity evaluation system. Finally, the effect of the combination of regional sand and Carbo proppant on the conductivity was studied, under the same sand placement concentration and mesh number of proppant. The results of laboratory experiments show that the hardness and density of regional sand are higher than that of Carbo proppant, but the sphericity of regional sand is smaller than that of Carbo proppant. Under the same sand placement concentration, the regional sand conductivity of 30/50 meshes was higher than that of 40/70 meshes. As the concentration of sand placement increases, the ability of regional sand conductivity increases. The conductivity of a 1:1 mixture of regional sand and Carbo quartz is comparable to that of all Carbo quartz. According to the application examples of adjacent Wells A and B in block X of Xinjiang oilfield, the project that the ratio of regional sand to Carbo proppant is 1:1 can guarantee stable and effective flow conductivity and save fracturing cost.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"4 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":"115616468","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":"Experiments on Fluid Placement in a Confined Pipe: Fluid Mechanics Analysis for Plug and Abandonment Applications","authors":"Soheil Akbari, S. Taghavi","doi":"10.1115/omae2020-18077","DOIUrl":"https://doi.org/10.1115/omae2020-18077","url":null,"abstract":"\u0000 Plug and abandonment (P&A) of oil and gas wells is an essential process to prevent the oil and gas reservoir fluids migration over time and possibly contaminating other formations and also fresh water resources. In order to plug and abandon a well, a high quality cement plug placement is required. One of the most common methods of cement plug placement is the dump bailing method. In this method, a fixed volume of cement is dumped using a bailer on a mechanical plug in the wellbore. The cement slurry occupies the wellbore and also the annular region outside the dump bailer. In the processes of cement slurry placement, an extensive range of Newtonian or non-Newtonian fluids is used to remove the in-situ fluid (drilling fluid or water) in the wellbore. Based on the large number of parameters such as the density and viscosity differences between the fluids, the geometry type (pipe, annulus, etc.), the operation conditions (velocity, geometry inclination, dumping height), various kinds of placement and mixing flows can occur, and different flow regimes (e.g. inertial, viscous) can develop. In this paper, we experimentally study the placement of a heavy fluid to replace an in-situ light fluid in an inclined closed-end pipe (representative of the dump bailing method). The two fluids are Newtonian and miscible, and they have the same viscosity. We investigate the effects of some of the flow parameters such as the dumping height, the pipe inclination, and the inflow velocity of the heavy fluid on the degree of mixing and the placement quality and efficiency. Our results show that the the most efficient displacement happens with the shortest dumping height and at lower inclination from vertical. Also, a high inflow velocity displaces the light fluid promptly with more mixing in comparison with a low inflow rate. The results can help us to develop strategies for improving the dump bailing method in the P&A of the oil and gas wells.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"3 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":"128659078","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 Simple and Effective Method to Predict the Generation of Black Carbon in Oilfields","authors":"Dai Guohua, Yufei Wan, Chunyu Liu, Sang-ho Jun, Wenguang Wang, Xin Qian, Ming Hao, Renwei Liu","doi":"10.1115/omae2020-18432","DOIUrl":"https://doi.org/10.1115/omae2020-18432","url":null,"abstract":"\u0000 As an important safety discharge facility in petrochemical industry, flare is widely used in offshore and onshore oil and gas fields to relieve pressure, vent unwanted gases. This open-air combustion system oxidizes the fuel gases into carbon dioxide and water vapor and hence avoids the contamination of air with harmful gases that cause air pollution and climate change. With the increasingly strict requirements of environmental protection and the implementation of low-carbon development policy, the black carbon (soot) caused by incomplete combustion from the flare will be strictly controlled. At present, there is no simple and effective method to determine whether the flare produces visible black carbon which exacerbates the pollution. According to the investigation on site, there are different degrees of black carbon emission from the flares both in the onshore and offshore oilfield, which brings some troubles to the petroleum corporation. Based on a flare tip and the associated gas from an oilfield in Bohai Bay of China, a simulation model, which in accordance with the actual situation, was established with the Computational Fluid Dynamics software. The Non-Premixed Combustion model was used to simulate the Combustion, the P-1 model was adopted to calculate the thermal radiation and the Moss-Brookes model was selected to compute the generation of black carbon. The feasibility of the model was demonstrated by comparing the simulation results with the field test results. Then the limitation of current conventional practice to predict whether the soot is produced, was demonstrated with the model. At the same time, the production rate of black carbon under different conditions of components and fraction were calculated. After a comprehensive analysis and comparison, a simple, directly and effective method to predict the soot was proposed. When the C-to-H ratio of fuel gas is greater than 0.273, it tends to visible soot, and when the C-to-H ratio is greater than 0.285, it tends to heavy soot, which is in line with the actual in site. Therefore, the method can be applied to predict the level of the generation of black carbon in the engineering.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"5 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":"129140862","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":"Real-Time Well Monitoring and Engineering Analysis of Drilling Activities: Intelligent Rig State Detection and Prediction With Uncertainty","authors":"Kemajou Vanessa Ndonhong, Robello Samuel","doi":"10.1115/omae2020-18060","DOIUrl":"https://doi.org/10.1115/omae2020-18060","url":null,"abstract":"\u0000 Drilling activities are risky and costly, especially when performed offshore. Careful monitoring and real time data analysis are required for safe and efficient operations with minimized down-time. Drilling operations, being fast-paced and not visible, often lead to transient and unforeseen issues. The synchronous assessment and prediction of drilling quality has historically been a challenge. It relies on a prompt collection, analysis and prediction of the multiple sensors data, as well as an immediate comparison to the original drilling plan. Another challenge is achieving real-time well engineering, and automatically and instantaneously providing valuable insights to the engineering and operations teams. A system was successfully developed to tackle these challenges. It is a cloud-based application, made with an event-driven streaming architecture to automatically retrieve real-time drilling data and compare it with planned data. The real-time data is automatically made available to determine the current well operation or rig state, and trigger the subsequent engineering analysis. Next, a forecast model is trained with the engineering calculation outputs and it returns predictions on these outputs while considering their inherent uncertainty. As a result, these predictions enable alerts to be sent when the system detects approaching anomalous conditions. The proposed system is a DecisionSpace® 365 cloud-native application on an open architecture. It is flexible, accessible from anywhere, can be automatically updated for continuous improvement, and can be deployed easily and quickly. It can also be extended to further applications.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"32 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":"121520033","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":"Stable Triple-Layer Lubricated Pipeline Flow","authors":"P. Sarmadi, S. Hormozi, I. Frigaard","doi":"10.1115/omae2020-19094","DOIUrl":"https://doi.org/10.1115/omae2020-19094","url":null,"abstract":"\u0000 Recently we have introduced a novel methodology for efficient transport of heavy oil via a triple-layer core-annular flow [1]. Pumping pressures are significantly reduced by concentrating high shear rates to a lubricating layer, while ideas from visco-plastic lubrication were used to eliminate interfacial instabilities. We purposefully position a shaped unyielded skin of a visco-plastic fluid between the transported oil and the lubricating fluid layer. The shaping of the skin layer allows for lubrication forces to develop and balance the density difference between the fluids. Here we show an explicit advantage of the proposed method. Essentially the method can give stable flows for a very wide range of fluid input ratio, although not all will produce the desired reduction in frictional pressure losses. Additionally, we use the extensional flow method derived in [2] to estimate the required yield stress to maintain the skin completely unyielded.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"44 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":"123767944","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}