Near Wellbore Two-Phase Effect of a Light Oil Field

2018 ◽  
Author(s):  
Zhaocong Zhou ◽  
Andrea Lamberti ◽  
Andrea Locci ◽  
Valerio Parasiliti ◽  
Paolo Prevosti ◽  
...  
Keyword(s):  
Oil Field ◽  
Phase Effect ◽  
Two Phase ◽  
Light Oil

Calculating Method for the Solid Phase Effect Coefficient of the Solid-Fluid Two Phase Flow Centrifugal Pump

2010 ◽  
Vol 29-32 ◽  
pp. 658-663
Author(s):  
Chuan Jun Li ◽  
Gang Yu ◽  
Xin Wang
Keyword(s):  
Differential Equation ◽  
Centrifugal Pump ◽  
Two Phase Flow ◽  
Solid Phase ◽  
High Accuracy ◽  
Phase Flow ◽  
Phase Effect ◽  
Two Phase ◽  
Error Band ◽  
Calculating Method

In order to acquire the solid-fluid two phase flow centrifugal pump’s slurry head according with the fact, the solid phase effect coefficient must be calculated precisely. By analysising the acting forces on the solid particle, its moving differential equation was established. And the calculating formula of the solid phase effect coefficient was deduced based on the equation. For the sake of verifying its validity, a test of contrast and comparison on the calculating slurry heads by some ways was carried out. The results shows that the relative error values of the slurry head calculated are less than 2.00% with a small and stably error band. The method has the advantage of simple calculating process, high accuracy, low randomness and good practicability.

Understanding ESP Performance Under High Viscous Applications and Emulsion Production

2021 ◽  
Author(s):  
Luiz Pastre ◽  
Jorge Biazussi ◽  
William Monte Verde ◽  
Antonio Bannwart
Keyword(s):  
High Viscosity ◽  
Field Application ◽  
Oil Field ◽  
Two Phase ◽  
Water Emulsion ◽  
Technical Requirements ◽  
Artificial Lift ◽  
Controlled Environments ◽  
Oil Water ◽  
Field Deployment

Abstract Although being widely used as an artificial lift method for heavy oil field developments, Electrical Submersible Pump (ESP) performance in high viscous applications is not fully understood. In order to improve knowledge of pump behavior under such conditions, Equinor has developed stage qualification tests as part of the technical requirements for deploying ESPs in Peregrino Field located offshore Brazil and has funded a series of research efforts to better design and operate the system more efficiently. Qualification tests were made mandatory for every stage type prior to field deployment in Peregrino. It is known that the affinity laws don´t hold true for high viscosity applications. Therefore, extensive qualification tests are required to provide actual stage performance in high viscous applications. Test results are used to optimize ESP system design for each well selecting the most efficient stage type considering specific well application challenges. In addition, the actual pump performance improves accuracy in production allocation algorithms. A better understanding of ESP behavior in viscous fluid application helps improving oil production and allows ESP operation with higher efficiency, increasing system run life. Shear forces inside ESP stages generate emulsion that compromises ESP performance. Lab tests in controlled environments have helped Equinor to gather valuable information about emulsion formation and evaluate ESP performance in conditions similar to field application. Equinor has funded studies to better understand two-phase flow (oil-water) which allowed visualization and investigation of oil drops dynamics inside the impeller. In addition, experimental procedures were proposed to investigate the effective viscosity of emulsion at pump discharge and the phase inversion hysteresis in the transition water-oil and oil-water emulsion. In addition to qualification tests and research performed to better understand system behavior, Equinor has developed and improved procedures to operate ESP systems in high viscous applications with emulsion production during 10 years of operation in Peregrino field. Such conditions also impose challenges to ESP system reliability. Over the years, Equinor has peformed failure analysis to enhance ESP system robustness which, combined with upper completion design, have improved system operation and reliability decreasing operating costs in Peregrino field.

Cuttings Characteristics and Mechanics Behavior in Horizontal Wells of Liaohe Oil Field

2013 ◽  
Vol 316-317 ◽  
pp. 842-845
Author(s):  
Xian Zhong Yi ◽  
Jun Feng Zhang ◽  
Sheng Zong Jiang
Keyword(s):  
Flow Characteristics ◽  
Oil Field ◽  
Cuttings Transport ◽  
Two Phase ◽  
Fluid Medium ◽  
Washing Process ◽  
Three Phase ◽  
Flow Phenomena ◽  
Phase Liquid ◽  
Cuttings Bed

Cuttings transport of drilling and washing process in horizontal well is a typical two-phase (liquid-solid) or three-phase (gas-liquid-solid) flow phenomena. In this paper, it analyzes the flow characteristics of Huan 127-Lian H2 horizontal wellbore , then uses experimental method to study the behavior of the particle size distribution and the mechanics. This study provides an important way to master cuttings settling in fluid medium, it can explain how the cuttings bed is generated and cleared, and why the procession of cuttings of migration is stopped. In addition, measurement and analysis of drill cuttings is the basis erosion and abrasion analysis of BHA.

Analysis of the Operation Mode and Instability on the Low-Flowrate Running of Hot-Oil Pipeline

2012 ◽  
Vol 614-615 ◽  
pp. 550-554
Author(s):  
Rong Ge Xiao ◽  
Dong Rui Yi ◽  
Pei Fen Yao ◽  
Jia Quan Zhou
Keyword(s):  
Crude Oil ◽  
Oil And Gas ◽  
Operation Mode ◽  
Natural Aging ◽  
Oil Field ◽  
Oil Refining ◽  
Oil Pipeline ◽  
Point Depressant ◽  
Light Oil ◽  
Reduced Costs

Because the most of crude oil has the nature of "three-high" in China and the natural aging of crude oil in the part of oil field, the transmission of crude-oil has reduced, and the oil refining has increased in oil field, Thus the majority of pipelines laid in china are running at a low-flowrate. Analysis of the problems in the running of low-flowrate pipeline: with the temperature drops up, the viscosity increases; the accident of condensate tubes very easily occurs; the turnover point increases; the pressure load of pipeline increases; the supply of heat is shortage, the reliability of equipment is reduced; costs increases and so on. There is proposing the main operation mode to solve the pipeline in low-flowrate, including intermittent transportation, the transportation of mixing light oil, oil and gas batch transportation, the transportation with adding pour point depressant and so on, and has discussed the instability of the running of hot pipeline in the low-flowrate.

Production of Light Oil from a Shallow Frozen Reservoir: A Redevelopment Case Study of the Umiat Oil Field, Northern Alaska

2011 ◽  
Author(s):  
Catherine Hanks ◽  
Grant Shimer ◽  
Jeremy Davis ◽  
Raelene Wentz ◽  
Vasil Godabrelidze ◽  
...  
Keyword(s):  
Oil Field ◽  
Light Oil ◽  
Northern Alaska

scholarly journals Change in the Structure of Asphaltene Macromolecules of the Krapivinskoye Oil Field During Biological Oxidation

2021 ◽  
pp. 252-262
Author(s):  
Tatyana V. Cheshkova ◽  
Tatyana A. Sagachenko ◽  
Raisa S. Min ◽  
Dmitriy A. Philatov
Keyword(s):  
Structural Parameters ◽  
Soil Microflora ◽  
Oil Field ◽  
Microbial Oxidation ◽  
Physico Chemical ◽  
Composition And Structure ◽  
Chromatomass Spectrometry ◽  
Saturated And Aromatic Hydrocarbons ◽  
Chemical Destruction ◽  
Light Oil

Using physico-chemical methods of research (elemental analysis, infrared spectroscopy, selective chemical destruction of sulfide and ester bonds, chromatomass spectrometry) the influence of biodegradation processes on the composition and structure of asphaltenes of light oil at the Krapivinskoye deposit was studied. The results of comparative characteristics of initial asphaltenes and asphaltenes after biodestruction are presented. Attention is paid to studying their structural parameters and composition of fragments bound in asphaltene molecules through ester and sulfide bridges. It has been shown that microbial oxidation of asphaltenes of light oil by aboriginal soil microflora (laboratory experiment) occurs through a series of catalytic processes with formation of intermediate products of transformation – alcohols, aldehydes, ketones and fatty acids. It has been established that “grey and ether-bound” fragments in asphaltene molecules of biodegradable oil differ from “bound” compounds in the structure of the original asphaltenes with the qualitative composition of saturated and aromatic hydrocarbons and heteroatomic components

Challenges, Opportunities and Threats of Deep Bottoms-Up Water Injection in Heavy Oil Reservoir: Lessons Learnt from the G Field, South Oman

2021 ◽  
Author(s):  
Chaitanya Behera ◽  
Sandip Mahajan ◽  
Carlos Annia ◽  
Mahmood Harthi ◽  
Jane-Frances Obilaja ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Water Injection ◽  
Field Performance ◽  
Oil Field ◽  
Oil Fields ◽  
Reservoir Pressure ◽  
Light Oil ◽  
Alternative Water ◽  
Variable Water

Abstract This paper presents the results of a comprehensive study carried out to improve the understanding of deep bottom-up water injection, which enabled optimizing the recovery of a heavy oil field in South Oman. Understanding the variable water injection response and the scale of impact on oil recovery due to reservoir heterogeneity, operating reservoir pressure and liquid offtake management are the main challenges of deep bottoms-up water injection in heavy oil fields. The offtake and throughput management philosophy for heavy oil waterflood is not same as classical light oil. Due to unclear understanding of water injection response, sometimes the operators are tempted to implement alternative water injection trials leading to increase in the risk of losing reserves and unwarranted CAPEX sink. There are several examples of waterflood in heavy oil fields; however, very few examples of deep bottom water injection cases are available globally. The field G is one of the large heavy oil fields in South Oman; the oil viscosity varies between 250cp to 1500cp. The field came on-stream in 1989, but bottoms-up water-injection started in 2015, mainly to supplement the aquifer influx after 40% decline of reservoir pressure. After three years of water injection, the field liquid production was substantially lower than predicted, which implied risk on the incremental reserves. Alternative water injection concepts were tested by implementing multiple water injection trials apprehending the effectiveness of the bottoms-up water injection concept. A comprehensive integrated study including update of geocellular model, full field dynamic simulation, produced water re-injection (PWRI) model and conventional field performance analysis was undertaken for optimizing the field recovery. The Root Cause Analysis (RCA) revealed many reasons for suboptimal field performance including water injection management, productivity impairment due to near wellbore damage, well completion issues, and more importantly the variable water injection response in the field. The dynamic simulation study indicated negligible oil bank development due to frontal displacement and no water cut reversal as initial response to the water injection. Nevertheless, the significance of operating reservoir pressure, liquid offtake and throughput management impact on oil recovery cann't be precluded. The work concludes that the well reservoir management (WRM) strategy for heavy oil field is not same as the classical light oil waterflood. Nevertheless, the reservoir heterogeneity, oil column thickness and saturation history are also important influencing factors for variable water injection response in heavy oil field.

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