A Case Study of a Successful Chemical Treatment to Mitigate Asphaltene Precipitation and Deposition in Light Crude Oil Field

2006 ◽  
Author(s):  
Akira Sanada ◽  
Yoshihiro Miyagawa
Keyword(s):  
Crude Oil ◽  
Chemical Treatment ◽  
Oil Field ◽  
Asphaltene Precipitation ◽  
Light Crude Oil

scholarly journals Chemical study of asphaltene inhibitors effects on asphaltene precipitation of an Iranian oil field

2020 ◽  
Vol 75 ◽  
pp. 6 ◽  
Author(s):  
Afshar Ahmadbaygi ◽  
Behrouz Bayati ◽  
Mohsen Mansouri ◽  
Hossein Rezaei ◽  
Masoud Riazi
Keyword(s):  
Fourier Transform ◽  
Crude Oil ◽  
Ftir Spectroscopy ◽  
Chemical Structure ◽  
Chemical Study ◽  
Oil Field ◽  
Asphaltene Precipitation ◽  
Spectroscopy Analysis ◽  
Synthetic Oil ◽  
Onset Point

The amount of precipitated asphaltene can be considerably reduced with pretreatment of asphaltene inhibitor, in the crude oil. Efficiency of asphaltene inhibitors mainly depends on some parameters such as pH of the oil and the chemical structure of asphaltene inhibitors. In this paper, the amounts of asphaltene precipitation have been experimentally measured using two n-paraffin precipitants; n-heptane and n-hexane. The performance of the studies on the asphaltene accumulation was studied using Fourier-Transform Infrared (FTIR) Spectroscopy analysis. The onset point has been determined by three different commercial asphaltene inhibitors. The results show that when an asphaltene inhibitor is not injected into the mixture of synthetic oil/n-heptane, AOP (Asphaltene Onset Point) occurs at 35 vol.% of n-heptane, while with addition of 3000 ppm of asphaltene B inhibitor, AOP occurs at 60 vol.% of n-heptane.

scholarly journals Dynamics of Changes in Composition and Stability of the Heavy Oil Sampled from the Usinskoye Oil Field as a Result of Formation Treatment with a Sol-Forming EOR System

2019 ◽  
pp. 464-472
Author(s):  
Darya I. Chuikina ◽  
Tatiana V. Petrenko ◽  
Larisa D. Stakhina
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Oil Field ◽  
Aggregative Stability ◽  
Heavy Oils ◽  
Asphaltene Precipitation ◽  
Liquid Adsorption ◽  
Oil Displacement ◽  
Before And After

The paper deals with a sol-forming system for oil recovery enhancement (EOR system) used to increase the rate of heavy oil displacement. The effect of sol-forming EOR system during the heavy oil displacement on the composition and stability of oil sampled from the Usinskoye oil field of Russia is investigated. The composition of a crude oil also plays an important role in changing its stability. The work is aimed to investigate stability of heavy crude oil in regards to asphaltene precipitation. For asphaltene toluene/n-heptane solutions, the aggregation stability of asphaltenes based on сhange in the optical density with time is investigated via spectrophotometry. SARA analysis is used to characterize the compositions of heavy oils. First, the content of asphaltenes precipitated from the oil samples is determined and then the samples of deasphalted crude oil (maltenes) are analyzed by the method of liquid adsorption chromatography for the purpose to study the composition of oil sampled from the wells before and after their treatment with the sol-forming EOR system. It is found out that the treatment of reservoir crude oil with the sol-forming EOR system results in changes in composition of saturated, aromatic hydrocarbons, resins, and asphaltenes (SARA components) and aggregative stability of produced oil. The results obtained showed that the aggregative stability of heavy oil depends not only on the content of SARA components in the dispersion medium but on the presence of metalloporphyrins in the oil. Metalloporphyrins could act as inhibitors of asphaltene precipitation, which is an additional factor responsible for the stabilization of the oil dispersed system

Construction, Validation, and Application of Digital Oil: Investigation of Asphaltene Association Toward Asphaltene-Precipitation Prediction

SPE Journal ◽  
2018 ◽  
Vol 23 (03) ◽  
pp. 952-968 ◽  
Author(s):  
S.. Sugiyama ◽  
Y.. Liang ◽  
S.. Murata ◽  
T.. Matsuoka ◽  
M.. Morimoto ◽  
...  
Keyword(s):  
Experimental Data ◽  
Liquid Phase ◽  
Crude Oil ◽  
Md Simulation ◽  
Heavy Fraction ◽  
Liquid Density ◽  
Asphaltene Precipitation ◽  
Viscosity Change ◽  
Light Crude Oil ◽  
Wide Range

Summary Digital oil, a realistic molecular model of crude oil for a target reservoir, opens a new door to understand properties of crude oil under a wide range of thermodynamic conditions. In this study, we constructed a digital oil to model a light crude oil using analytical experiments after separating the light crude oil into gas, light and heavy fractions, and asphaltenes. The gas and light fractions were analyzed by gas chromatography (GC), and 105 kinds of molecules, including normal alkanes, isoalkanes, naphthenes, alkylbenzenes, and polyaromatics (with a maximum of three aromatic rings), were directly identified. The heavy fraction and asphaltenes were analyzed by elemental analysis, molecular-weight (MW) measurement with gel-permeation chromatography (GPC), and hydrogen and carbon nuclear-magnetic-resonance (NMR) spectroscopy, and represented by the quantitative molecular-representation method, which provides a mixture model imitating distributions of the crude-oil sample. Because of the low weight concentration of asphaltenes in the light crude oil (approximately 0.1 wt%), the digital oil model was constructed by mixing the gas, light-, and heavy-fraction models. To confirm the validity of the digital oil, density and viscosity were calculated over a wide range of pressures at the reservoir temperature by molecular-dynamics (MD) simulations. Because only experimental data for the liquid phase were available, we predicted the liquid components of the digital oil at pressures lower than 16.3 MPa (i.e., the bubblepoint pressure) by flash calculation, and calculated the liquid density by MD simulation. The calculated densities coincided with the experimental values at all pressures in the range from 0.1 to 29.5 MPa. We calculated the viscosity of the liquid phase at the same pressures by two independent methods. The calculated viscosities were in good agreement with each other. Moreover, the viscosity change with pressure was consistent with the experimental data. As a step for application of digital oil to predict asphaltene-precipitation risk, we calculated dimerization free energy of asphaltenes (which we regarded as asphaltene self-association energy) in the digital oil at the reservoir condition, using MD simulation with the umbrella sampling method. The calculated value is consistent with reported values used in phase-equilibrium calculation. Digital oil is a powerful tool to help us understand mechanisms of molecular-scale phenomena in oil reservoirs and solve problems in the upstream and downstream petroleum industry.

scholarly journals Asphaltene Deposition during CO2 Flooding in Ultralow Permeability Reservoirs: A Case Study from Changqing Oil Field

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-14
Author(s):  
Li Rong-tao ◽  
Liao Xin-wei ◽  
Zou Jian-dong ◽  
Gao Chang-wang ◽  
Zhao Dong-feng ◽  
...  
Keyword(s):  
Adverse Effects ◽  
Injection Rate ◽  
Oil Field ◽  
Formation Damage ◽  
Co2 Flooding ◽  
Asphaltene Precipitation ◽  
Asphaltene Content ◽  
Asphaltene Deposition ◽  
Ultralow Permeability

Asphaltene deposition is a common phenomenon during CO2 flooding in ultralow permeability reservoirs. The deposited asphaltene occupies the pore volume and decreases permeability, resulting in serious formation damage and pore well productivity. It is urgent to investigate the asphaltene deposition mechanisms, adverse effects, and preventive measures. However, few asphaltene deposition investigations have been systematically conducted by now. In this research, the asphaltene precipitation mechanisms and adverse effects were comprehensively investigated by using experimental and numerical methods. To study the effects of pressure, asphaltene content, and temperature on asphaltene precipitation qualitatively and quantitatively, the microscope visible detection experiment and the PVT cell static experiment were firstly conducted. The adverse effects on porosity and permeability resulted from asphaltene deposition were also studied by the core flooding experiment. Secondly, simulation models of asphaltene precipitation and deposition were developed and validated by experimental data. Finally, a case study from Changqing oil field was presented to analyze the asphaltene deposition characteristic and preventive measures. The experimental results showed that the asphaltene precipitation increases with the increased pressure before reaching the minimum miscible pressure (MMP) and gets the peak value around the MMP, while decreases slowly. The asphaltene precipitation increases with the increased temperature and asphaltene content. The variation trend of adverse effects on porosity and permeability resulted from asphaltene deposition is similar to that of asphaltene precipitation under the influence of pressure, asphaltene content, and temperature. The case study shows that the water-altering-gas (WAG) with high injection rate suffers more serious asphaltene deposition compared with the WAG with low injection rate, for the asphaltene precipitation increases as the increased pressure before reaching the MMP. The CO2 continuous injection with high injection rate is the worst choice, for low sweep efficiency and the most severe formation damage. Thus, the WAG with optimal injection rate was proposed to maintain well productivity and to reduce formation damage resulted from asphaltene deposition during developing ultralow permeability reservoirs.

scholarly journals Modifying an Equation to Predict the Asphaltene Deposition in the Buzurgan Oil Field

2020 ◽  
Vol 21 (4) ◽  
pp. 49-55
Author(s):  
Raad Mohammed Hasan ◽  
Ayad A. Al-haleem
Keyword(s):  
Crude Oil ◽  
Oil Field ◽  
Original Equation ◽  
Instability Index ◽  
Asphaltene Precipitation ◽  
Oil Companies ◽  
Reservoir Rocks ◽  
Reservoir Conditions ◽  
The Difference ◽  
New Equation

Buzurgan oil field suffers from the phenomenon of asphaltene precipitation. The serious negatives of this phenomenon are the decrease in production caused by clogging of the pores and decrease in permeability and wettability of the reservoir rocks, in addition to the blockages that occur in the pipeline transporting crude oil. The presence of laboratories in the Iraqi oil companies helped to conduct the necessary experiments, such as gas chromatography (GC) test to identify the components of crude oil and the percentages of each component, These laboratory results consider the main elements in deriving a new equation called modified colloidal instability index (MCII) equation based on a well-known global equation called colloidal instability index (CII) equation.    The modified (MCII) equation is considered an equation compared to the original (CII) equation because both equations mainly depend on the components of the crude oil, but the difference between them lies in the fact that the original equation depends on the crude oil components at the surface conditions, while the new equation relies on the analysis of crude oil to its basic components at reservoir conditions by using (GC) analysis device.    The components of the crude oil in the reservoir conditions according to the number of carbon atoms of each component compared with the elements of the original equation, which are (saturates, aromatics, resins, and asphaltene).    The new MCII equation helps in predicting the possibility of asphaltene precipitation which can be used and generalized to other Iraqi oilfields as it has proven its worth and acceptability in this study.

In situ bioremediation of crude oil contaminated site: A case study in Jianghan oil field, China

2016 ◽  
Vol 34 (1) ◽  
pp. 63-70 ◽  
Author(s):  
G. L. Xu ◽  
H. Liu ◽  
M. J. Li ◽  
Z. M. Li ◽  
Z. H. Peng ◽  
...  
Keyword(s):  
Crude Oil ◽  
Oil Field ◽  
Contaminated Site ◽  
In Situ Bioremediation

scholarly journals Cardanol /SiO2 Nanocomposites for Inhibition of Formation Damage by Asphaltene Precipitation/Deposition in Light Crude Oil Reservoirs. Part II: Nanocomposite Evaluation and Coreflooding Test

ACS Omega ◽  
2020 ◽  
Vol 5 (43) ◽  
pp. 27800-27810
Author(s):  
Daniel López ◽  
Juan E. Jaramillo ◽  
Elizabete F. Lucas ◽  
Masoud Riazi ◽  
Sergio H. Lopera ◽  
...  
Keyword(s):  
Crude Oil ◽  
Oil Reservoirs ◽  
Formation Damage ◽  
Asphaltene Precipitation ◽  
Light Crude Oil ◽  
Sio2 Nanocomposites

Effect of pressure and CO2 content on the asphaltene precipitation in the light crude oil

2019 ◽  
Vol 38 (2) ◽  
pp. 116-123
Author(s):  
Jianguang Wei ◽  
Jiangtao Li ◽  
Xiaofeng Zhou ◽  
Xin Zhang
Keyword(s):  
Crude Oil ◽  
Asphaltene Precipitation ◽  
Effect Of Pressure ◽  
Light Crude Oil
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