Multivariate Analysis of Crude Oil Composition and Fluid Properties Used in Multiphase Flow Metering (MFM)

2012 ◽  
Vol 26 (9) ◽  
pp. 5679-5688 ◽  
Author(s):  
Andreas L. Tomren ◽  
Tanja Barth ◽  
Kjetil Folgerø
Keyword(s):  
Multivariate Analysis ◽  
Multiphase Flow ◽  
Crude Oil ◽  
Oil Composition ◽  
Flow Metering ◽  
Fluid Properties

scholarly journals A Microwave Sensing and Imaging Method for Multiphase Flow Metering of Crude Oil Pipes

2020 ◽  
Vol 13 ◽  
pp. 1286-1297
Author(s):  
Fatemeh Modares Sabzevari ◽  
Robert S. C. Winter ◽  
Daniel Oloumi ◽  
Karumudi Rambabu
Keyword(s):  
Multiphase Flow ◽  
Crude Oil ◽  
Imaging Method ◽  
Flow Metering

scholarly journals A multi-resolution and multivariate analysis of the dynamic relationships between crude oil and petroleum-product prices

2018 ◽  
Vol 228 ◽  
pp. 1550-1560 ◽  
Author(s):  
Josué M. Polanco Martínez ◽  
Luis M. Abadie ◽  
J. Fernández-Macho
Keyword(s):  
Multivariate Analysis ◽  
Crude Oil ◽  
Petroleum Product ◽  
Dynamic Relationships

Coupled Heat and Mass Transfer CFD Model for Methane Hydrate

2015 ◽  
Author(s):  
Eugenio Turco Neto ◽  
M. A. Rahman ◽  
Syed Imtiaz ◽  
Thiago dos Santos Pereira ◽  
Fernanda Soares de Sousa
Keyword(s):  
Natural Gas ◽  
Multiphase Flow ◽  
Gas Hydrate ◽  
Gas Flow ◽  
Three Dimensional ◽  
Hydrate Formation ◽  
Cfd Model ◽  
Flow Metering ◽  
Ansys Cfx ◽  
Gas Hydrate Formation

The gas hydrates problem has been growing in offshore deep water condition where due to low temperature and high pressure hydrate formation becomes more favorable. Several studies have been done to predict the influence of gas hydrate formation in natural gas flow pipeline. However, the effects of multiphase hydrodynamic properties on hydrate formation are missing in these studies. The use of CFD to simulate gas hydrate formation can overcome this gap. In this study a computational fluid dynamics (CFD) model has been developed for mass, heat and momentum transfer for better understanding natural gas hydrate formation and its migration into the pipelines using ANSYS CFX-14. The problem considered in this study is a three-dimensional multiphase-flow model based on Simon Lo (2003) study, which considered the oil-dominant flow in a pipeline with hydrate formation around water droplets dispersed into the oil phase. The results obtained in this study will be useful in designing a multiphase flow metering and a pump to overcome the pressure drop caused by hydrate formation in multiphase petroleum production.

scholarly journals Bioremediation of clayey soil contaminated with crude oil: comparison of dynamic and static biopiles in lab-scale

2017 ◽  
Author(s):  
Jorge Antonio Lopes ◽  
Graciane Silva ◽  
Marcia Marques ◽  
Sérgio Machado Correa
Keyword(s):  
Crude Oil ◽  
Contaminated Soil ◽  
Organic Contaminants ◽  
Clayey Soil ◽  
Total Petroleum Hydrocarbons ◽  
Oil Composition ◽  
Polycyclic Aromatic ◽  
Forced Aeration ◽  
Total Fungi ◽  
Technological Options

Bioremediation of aged and newly clayey soil contaminated with crude oil was investigated in lab-scale using two different strategies (biostimulation-BIOS and bioaugmentation-BIOA), also simulating two different technological options: dynamic biopile (M) and static biopile with forced aeration (B). The inoculum used for bioaugmentation was obtained from the aged contaminated soil. The treatments were performed in triplicates and included one control (original contaminated soil-CONT). The treatments were monitored with soil sampling obtained after 0, 24, 59 and 121 days when the populations of total heterotrophic microorganism (THM), total fungi (TF), and oil-degrading microorganism (ODM) as well as the extracted total petroleum hydrocarbons (TPH) and the 16 polycyclic aromatic hydrocarbons (PAH) prioritized by U.S. EPA were analyzed by gas chromatography. It was observed a trend for reduction of the microbial population density from 0 to 121 days. As expected, the population densities of THM and ODM were much higher in bio-augmented soils in both technologies (BIOA-m and BIOA-b) at day 0. However, after 121 days, the superiority in THM density was observed only in the bioreactor simulating static biopile with forced aeration (BIOA-b). Regarding treatment efficiency, the static biopile with forced aeration performed better in the removal of TPH when associated with bioaugmentation (BIOA-b), being equivalent to the microcosms (simulating dynamic biopile) for the other treatments (CONT and BIOS). For PAH, the superiority of the bioreactor was less conspicuous but observed in both bioremediation strategies (biostimulation BIOS-b and bioaugmentation BIOA-b). The results suggested that regarding TPH, the strategy of bioaugmentation was superior to biostimulation and that the bioreactor (simulating static biopile with forced aeration) reached better contaminant reductions than the microcosm (simulating dynamic biopile). Clayey soil contaminated with crude oil poses big challenges for the bioremediation, due to the texture of the soil favouring adsorption of organic contaminants and due to the complex crude oil composition. The bioprocesses are slow, cleavage of larger molecules are likely to generate smaller hydrocarbons and therefore the elimination of the toxicity is very slow, which may require longer periods and auxiliary tools, such as surfactants.

Artificial Intelligence and Data Analytics for Virtual Flow Metering

2021 ◽  
Author(s):  
Anton Gryzlov ◽  
Liliya Mironova ◽  
Sergey Safonov ◽  
Muhammad Arsalan
Keyword(s):  
Machine Learning ◽  
Multiphase Flow ◽  
Real Time ◽  
Production Control ◽  
Measurement Data ◽  
Sufficient Accuracy ◽  
Operating Conditions ◽  
Machine Learning Techniques ◽  
Flow Metering ◽  
Oil Gas

Abstract Modern challenges in reservoir management have recently faced new opportunities in production control and optimization strategies. These strategies in turn rely on the availability of monitoring equipment, which is used to obtain production rates in real-time with sufficient accuracy. In particular, a multiphase flow meter is a device for measuring the individual rates of oil, gas and water from a well in real-time without separating fluid phases. Currently, there are several technologies available on the market but multiphase flow meters generally incapable to handle all ranges of operating conditions with satisfactory accuracy in addition to being expensive to maintain. Virtual Flow Metering (VFM) is a mathematical technique for the indirect estimation of oil, gas and water flowrates produced from a well. This method uses more readily available data from conventional sensors, such as downhole pressure and temperature gauges, and calculates the multiphase rates by combining physical multiphase models, various measurement data and an optimization algorithm. In this work, a brief overview of the virtual metering methods is presented, which is followed by the application of several advanced machine-learning techniques for a specific case of multiphase production monitoring in a highly dynamic wellbore. The predictive capabilities of different types of machine learning instruments are explored using a model simulated production data. Also, the effect of measurement noise on the quality of estimates is considered. The presented results demonstrate that the data-driven methods are very capable to predict multiphase flow rates with sufficient accuracy and can be considered as a back-up solution for a conventional multiphase meter.

Research on the Relationship Between Crude Oil Composition and Asp Flooding Effect

2021 ◽  
Author(s):  
Zhe Sun ◽  
Xiaodong Kang ◽  
Shanshan Zhang
Keyword(s):  
Interfacial Tension ◽  
Crude Oil ◽  
Research Work ◽  
Practical Significance ◽  
Rock Surface ◽  
Composition Analysis ◽  
Oil Composition ◽  
Displacement Effect ◽  
Asp Flooding ◽  
The Relationship

Abstract In recent years, ASP flooding has been widely applied and obtained the remarkable effect. During the ASP flooding process, the oil composition has a great effect on the interfacial tension, which plays a vital role in the oil displacement effect. However, through literature research, few have made a profound study on the effect of oil composition on the recover rate. As a result, it is very important to carry out relevant research. For the oil sample (I) and sample (II) from two different regions in DQ, the crude oil composition analysis is first carried out. After the mixing of oil system and ASP system, the distribution ratio of agent is obtained. Furthermore, the oil composition does have an impact on the interfacial tension and recovery rate, and its influence law is explored. Finally, its application is introduced and analyzed. Research results show that, compare with sample (II), the sample (I) has more heavy components. After the mixing of oil samples and ASP, more surfactant and alkali enters into the oil phase of sample (I). Therefore, based on the similar miscibility principle, the surfactant is more likely to leave the oil water interface and enter into the oil phase of sample (I), which has a negative effect on reducing the interfacial tension. Furthermore, the phenomenon of chromatographic separation aggravates the adsorption of surfactant on rock surface. Therefore, combining the above factors, the oil increment effect of sample (I) becomes worse. In additional, the results of field test verify the laboratory experiments. From the above research, we canconclude that the relationship between crude oil composition and ASP flooding is of great significance. As a result, this paper has carried out a lot of related research work and revealed the internal relationship between the two, which has important practical significance to improve the effect of increasing oil and reducing water in ASP flooding technology.

Implementation of Instrumentalised Virtual Multiphase Flow Metering Technology in the Wells of the Vostochno-Makarovskoye Gas Condensate Field

2020 ◽  
Author(s):  
Andrey Zozulya ◽  
Vladimir Baranov ◽  
Mikhail Miletski ◽  
Konstantin Rymarenko ◽  
Marat Nukhaev ◽  
...  
Keyword(s):  
Multiphase Flow ◽  
Liquid Hydrocarbon ◽  
Operating Conditions ◽  
Gas Condensate ◽  
Flow Measurements ◽  
Hydrocarbon Production ◽  
Flow Meters ◽  
Well Production ◽  
Track Record ◽  
Flow Metering

Summary Liquid hydrocarbon quantity optimization is among key technological indicators in the gas condensate fields development. To achieve it one needs to select and maintain optimal well-operating conditions. In this case, multiphase flow measurements are prioritized as an important optimization tool. The article presents a proven record of implementing the technology of instrumentalised virtual multiphase flow metering in the wells of the Vostochno-Makarovskoye gas condensate field to increase the efficiency of liquid hydrocarbon production. Virtual flow metering technologies that use modeling methods and adapt models to actual well-operating parameters aiming at determining well production rates are becoming increasingly popular. At that, the quality of the data at the model input does not often guarantee a qualitative determination of multiphase flow parameters. This article presents a track record of building a virtual multiphase flow meter based on single-phase streamer flow meters mounted on gas wells. Venturi flow meters were used. A series of well tests were conducted in various modes. To configure the streamer model, additional tuning studies were conducted on the separator. While testing the wells, the results of constructing a streamer model were verified by nodal analysis.

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